Pumped heat electric storage system

ABSTRACT

The present disclosure provides pumped thermal energy storage systems that can be used to store and extract electrical energy. A pumped thermal energy storage system of the present disclosure can store energy by operating as a heat pump or refrigerator, whereby net work input can be used to transfer heat from the cold side to the hot side. A working fluid of the system is capable of efficient heat exchange with heat storage fluids on a hot side of the system and on a cold side of the system. The system can extract energy by operating as a heat engine transferring heat from the hot side to the cold side, which can result in net work output.

CROSS REFERENCE TO RELATED APPLICATIONS

This application claims the benefit of priority under 35 U.S.C. § 119(e) to U.S. Provisional Patent Application No. 62/936,491, filed Nov. 16, 2019, and U.S. Provisional Patent Application No. 63/113,386, filed Nov. 13, 2020. The disclosures set forth in the referenced applications are incorporated herein by reference in their entirety.

BACKGROUND

In a heat engine or heat pump, a heat exchanger may be employed to transfer heat between a thermal storage material and a working fluid for use with turbomachinery. The heat engine may be reversible, e.g., it may also be a heat pump, and the working fluid and heat exchanger may be used to transfer heat or cold to thermal storage media.

SUMMARY

A Pumped Heat Electric Storage (“PHES”) system may include at least a working fluid circulated through a closed cycle fluid path including at least two heat exchangers, at least one turbine, and at least one compressor. In some systems, one or more recuperative heat exchangers may also be included. At least two thermal reservoirs may hold thermal fluids which may be sent through the heat exchangers, providing thermal energy to, and/or extracting thermal energy from, the working fluid. One or more motor/generators may be used to obtain work from the thermal energy in the system, preferably by generating electricity from mechanical energy received from the turbine.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 schematically illustrates operating principles of a pumped heat electric storage system.

FIG. 2 is a top-level schematic diagram of a PHES system, according to an example embodiment.

FIG. 3 is a schematic fluid path diagram of a working fluid loop subsystem in a PHES system, according to an example embodiment.

FIGS. 3A-3D are schematic fluid path diagrams of a generation powertrain system and associated valves, according to example embodiments.

FIGS. 3E-3H are schematic fluid path diagrams of a charge powertrain system and associated valves, according to example embodiments.

FIGS. 3I-3J are schematic fluid path diagrams of an ambient cooler system and associated valves, according to example embodiments.

FIGS. 3K-3L are schematic fluid path diagrams of an ambient cooler system and associated valves, according to example embodiments.

FIG. 3M is a schematic fluid path diagram of an inventory control system, according to an example embodiment.

FIG. 3N is a schematic fluid path diagram of circulatory flow paths during charge mode.

FIG. 3O is a schematic fluid path diagram of circulatory flow paths during generation mode.

FIG. 4 is a schematic fluid path diagram of a hot-side thermal storage system, according to an example embodiment.

FIG. 5 is a schematic fluid path diagram of a cold-side thermal storage system, according to an example embodiment.

FIG. 6A is a schematic fluid path diagram of a main heat exchanger system, according to an example embodiment.

FIG. 6B is a schematic fluid path diagram of a main heat exchanger system, according to an example embodiment.

FIG. 7 is a schematic diagram of a generation powertrain (“GPT”) system, according to an example embodiment.

FIG. 8 is a schematic diagram of a charge powertrain (“CPT”) system, according to an example embodiment.

FIG. 9 is a schematic electrical diagram of a power interface, according to an example embodiment.

FIG. 10 illustrates primary modes of operation of a PHES system, according to an example embodiment.

FIG. 11 is a state diagram illustrating operating states of a PHES system, according to an example embodiment.

FIG. 12 is a state diagram illustrating select operating and transitional states of a PHES system, according to an example embodiment.

FIG. 13 is a state diagram illustrating select operating and transitional states of a PHES system, according to an example embodiment.

FIG. 14 is a state diagram illustrating generation powertrain states of a PHES system, according to an example embodiment.

FIG. 15 is a state diagram illustrating charge powertrain states of a PHES system, according to an example embodiment.

FIG. 16 is a state diagram illustrating generation powertrain valve states of a PHES system, according to an example embodiment.

FIG. 17 is a state diagram illustrating charge powertrain valve states of a PHES system, according to an example embodiment.

FIG. 18 is a state diagram illustrating ambient cooler states of a PHES system, according to an example embodiment.

FIG. 19 is a state diagram illustrating select operating and transitional states of a PHES system, according to an example embodiment.

FIG. 20 is a state diagram illustrating select operating and transitional states of a PHES system, according to an example embodiment.

FIG. 21 is a state diagram illustrating select operating and transitional states of a PHES system, according to an example embodiment.

FIG. 22 is a state diagram illustrating select operating and transitional states of a PHES system, according to an example embodiment.

FIG. 23 is a state diagram illustrating select operating and transitional states of a PHES system, according to an example embodiment.

FIG. 24 illustrates select controllers that can be implemented in a PHES system, according to an example embodiment.

FIG. 25 is a state diagram illustrating hot-side loop states of a PHES system, according to an example embodiment.

FIG. 26 is a state diagram illustrating cold-side loop states of a PHES system, according to an example embodiment.

DETAILED DESCRIPTION I. Overview

The Pumped Heat Electric Storage (“PHES”) systems, modes of operations, and states disclosed herein, as illustrated via multiple embodiments, are grid-scale energy storage systems that provide dispatchable power generation and power absorption. Advantageously, the PHES systems may provide increased grid stability and resilience. Additionally or alternatively, embodiments disclosed herein can achieve very fast dispatch response times, with spinning reserve capabilities comparable to natural gas peaker and cyclic units, but without the fossil fuel consumption. The PHES systems disclosed herein, utilizing thermal storage media also disclosed herein, may advantageously provide a safe, non-toxic and geography-independent energy (e.g., electricity) storage alternative.

The PHES systems function as thermodynamic cycle power generation and/or energy storage systems. Embodiments of the PHES systems may work as Brayton cycle systems. Alternatively or additionally, embodiments of the PHES systems may work as reversible Brayton cycle systems. Preferably, the PHES systems may operate as closed working-fluid loop systems. The PHES systems may use one or more generator and/or motor systems, which connect to one or more turbines and/or compressors which act on a working fluid (e.g., air) circulating in the system.

The PHES systems may have a hot side and a cold side. Each side may include one or more heat exchanger systems coupled to one or more thermal reservoirs. The PHES systems may employ liquid thermal storage medium on both or either the hot side and/or the cold side. The liquid thermal storage media preferably include liquids that are stable at high temperatures, such as molten nitrate salt or solar salt, and/or liquids that are stable at low temperatures, such as methanol/water coolant mixtures, glycols, and/or alkanes such as hexane. In one embodiment, cold-side and hot-side thermal reservoirs may include tanks of liquid thermal storage media, such as, but not limited to, methanol/water coolant and molten salt, respectively.

During a charge cycle (i.e, charge mode), the PHES systems act as a heat pump, converting electrical energy from an electrical grid or other source to thermal energy that is stored in thermal reservoirs. The heat-pumping action may be done via motor-driven turbomachinery (e.g., a compressor system and a turbine system) in a closed-loop Brayton cycle using a working fluid (e.g., air).

During a generation cycle (i.e., generation mode), the PHES systems act as a heat engine, converting stored thermal energy from the thermal reservoirs to electrical energy that can be dispatched back to the grid or another load. The working fluid loop during generation may be a closed-loop Brayton cycle, may use the same working fluid as the charge cycle, may use the same or different heat exchangers as the charge cycle, and may use the same turbomachinery as the charge cycle or may use different turbomachinery than the charge cycle. The generation turbine system may drive one or more generators that are grid synchronous.

Embodiments of the disclosed PHES systems enable fast cycling from full charge to full discharge.

Embodiments of the PHES systems also enable fast mode switching, such that the PHES system can switch modes from full load (i.e., charge) to full generation in a very short duration. This is particularly useful for providing spinning reserve type capabilities to address energy shifting needs related to high penetration of solar (e.g., photovoltaic) energy generation on an electrical grid or grid segment. During ramp periods when solar generation is coming online or going offline, the ability of the PHES systems to quickly change from full load to full generation is critical for helping to address slope of the solar “duck curve” that reflects a timing imbalance between peak demand and renewable energy production.

Embodiments of the PHES systems also enable partial turndown. Various power generation applications (e.g. wind farms, natural gas peaker power plants) benefit from the ability for generation and load assets such as the PHES systems to ramp power up and down from full power based on a dispatching signal.

FIG. 1 schematically illustrates operating principles of the PHES systems. Electricity may be stored in the form of thermal energy of two thermal storage media at different temperatures (e.g., thermal energy reservoirs comprising thermal storage media such as heat storage fluids) by using one or more heat pump and heat engine systems. In a charging (heat pump) mode, work may be consumed by the PHES system for transferring heat from a cold thermal medium to a hot thermal medium, thus lowering the temperature of the cold thermal medium and increasing the temperature of the hot thermal medium. In a generation (heat engine or discharging) mode, work may be produced by the PHES systems by transferring heat from the hot thermal medium to the cold thermal medium, thus lowering the temperature (i.e., sensible energy) of the hot thermal medium and increasing the temperature of the cold thermal medium. The PHES systems may be configured to ensure that the work produced by the system during generation is a favorable fraction of the energy consumed during charge. Excess heat from inefficiency may be dumped to ambient or an external heat sink. The PHES systems are configured to achieve high roundtrip efficiency, defined herein as the work produced by the system during generation divided by the work consumed by the system during charge. Further, the design of the PHES systems permits high roundtrip efficiency using components of a desired (e.g., acceptably low) cost.

The PHES systems may include a working fluid to and from which heat is transferred while undergoing a thermodynamic cycle. The PHES systems operating in a closed cycle allows, for example, a broad selection of working fluids, operation at elevated cold side pressures, operation at lower cold side temperatures, improved efficiency, and reduced risk of compressor and turbine damage. One or more aspects of the disclosure described in relation to the PHES systems having working fluids undergoing closed thermodynamic cycles may also be applied to the PHES systems having working fluids undergoing open or semi-open thermodynamic cycles.

The working fluid may undergo a thermodynamic cycle operating at one, two, or more pressure levels. For example, the working fluid may operate in a closed cycle between a low-pressure limit on a cold side of the system and a high-pressure limit on a hot side of the system. In some implementations, a low-pressure limit of about 10 atmospheres (atm) or greater can be used. In some instances, the low pressure limit may be at least about 1 atm, at least about 2 atm, at least about 5 atm, at least about 10 atm, at least about 15 atm, at least about 20 atm, at least about 30 atm, at least about 40 atm, at least about 60 atm, at least about 80 atm, at least about 100 atm, at least about 120 atm, at least about 160 atm, or at least about 200 atm, 500 atm, 1000 atm, or more. In some instances, a sub-atmospheric low-pressure limit may be used. For example, the low-pressure limit may be less than about 0.1 atm, less than about 0.2 atm, less than about 0.5 atm, or less than about 1 atm. In some instances, the low-pressure limit may be about 1 atmosphere (atm). In the case of a working fluid operating in an open cycle, the low-pressure limit may be about 1 atm or equal to ambient pressure.

Working fluids used in embodiments of the PHES systems may include air, argon, other noble gases, carbon dioxide, hydrogen, oxygen, or any combination thereof, and/or other fluids in gaseous state throughout the working fluid loop. In some implementations, a gas with a high specific heat ratio may be used to achieve higher cycle efficiency than a gas with a low specific heat ratio. For example, argon (e.g., specific heat ratio of about 1.66) may be used rather than air (e.g., specific heat ratio of about 1.4). In some cases, the working fluid may be a blend of one, two, three, or more fluids. In one example, helium (having a high thermal conductivity and a high specific heat) may be added to the working fluid (e.g., argon) to improve heat transfer rates in heat exchangers.

The PHES systems may utilize thermal storage media, such as one or more heat storage fluids. Alternatively or additionally, the thermal storage media may be solids or gasses, or a combination of liquids, solids, and/or gasses. The PHES systems may utilize a thermal storage medium on a hot side of the PHES system (“HTS medium”) and a thermal storage medium on a cold side of the system (“CTS medium”). Preferably, the thermal storage media have high heat capacities per unit volume (e.g., heat capacities above about 1400 Joule (kilogram Kelvin)−1) and high thermal conductivities (e.g., thermal conductivities above about 0.7 Watt (meter Kelvin)−1). In some implementations, several different thermal storage media on either the hot side or the cold side, or both the hot side and the cold side, may be used.

The operating temperatures and pressures of the HTS medium may be entirely in the liquid range of the HTS medium, and the operating temperatures and pressures of the CTS medium may be entirely in the liquid range of the CTS medium. In some examples, liquids may enable a more rapid exchange of large amounts of heat than solids or gases. Thus, in some cases, liquid HTS and CTS media may advantageously be used.

In some implementations, the HTS medium may be a molten salt or a mixture of molten salts. A salt or salt mixture that is liquid over the operating temperature range of the HTS medium may be employed. Molten salts can provide numerous advantages as thermal storage media, such as low vapor pressure, lack of toxicity, chemical stability, low reactivity with typical steels (e.g., melting point below the creep temperature of steels, low corrosiveness, low capacity to dissolve iron and nickel), and low cost. In one example, the HTS medium is a mixture of sodium nitrate and potassium nitrate. In another example, the HTS medium is a eutectic mixture of sodium nitrate and potassium nitrate. In another example, the HTS medium is a mixture of sodium nitrate and potassium nitrate having a lowered melting point than the individual constituents, an increased boiling point than the individual constituents, or a combination thereof. Other examples of HTS media include potassium nitrate, calcium nitrate, sodium nitrate, sodium nitrite, lithium nitrate, mineral oil, or any combination thereof. Further examples include any gaseous (including compressed gases), liquid or solid media (e.g., powdered solids) having suitable (e.g., high) thermal storage capacities and/or are capable of achieving suitable (e.g., high) heat transfer rates with the working fluid. For example, a mix of 60% sodium nitrate and 40% potassium nitrate (also referred to as a solar salt) can have a heat capacity of approximately 1500 Joule (Kelvin mole)−1 and a thermal conductivity of approximately 0.75 Watt (meter Kelvin)−1 within a temperature range of interest. Advantageously, the HTS medium may be operated in a temperature range that is compatible with structural steels used in unit components of the PHES system.

In some cases, liquid water at temperatures of about 0° C. to 100° C. (about 273 K-373 K) and a pressure of about 1 atm may be used as the CTS medium. Due to a possible explosion hazard associated with the presence of steam at or near the boiling point of water, the operating temperature can be kept below 100° C. while maintaining an operating pressure of 1 atm (i.e., no pressurization). In some cases, the temperature operating range of the CTS medium may be extended (e.g., to −30° C. to 100° C. at 1 atm) by using a mixture of water and one or more antifreeze compounds (e.g., ethylene glycol, propylene glycol, or glycerol), or a water/alcohol mixture such as water and methanol.

Improved efficiency may be achieved by increasing the temperature difference at which the PHES system operates, for example, by using a CTS medium capable of operating at lower temperatures. In some examples, the CTS medium may comprise hydrocarbons, such as, for example, alkanes (e.g., hexane or heptane), alkenes, alkynes, aldehydes, ketones, carboxylic acids (e.g., HCOOH), ethers, cycloalkanes, aromatic hydrocarbons, alcohols (e.g., butanol), other type(s) of hydrocarbon molecules, or any combinations thereof. In some examples, cryogenic liquids having boiling points below about −150° C. or about −180° C. may be used as CTS medium (e.g., propane, butane, pentane, nitrogen, helium, neon, argon, krypton, air, hydrogen, methane, or liquefied natural gas, or combinations thereof). In some implementations, choice of CTS medium may be limited by the choice of working fluid. For example, when a gaseous working fluid is used, a liquid CTS medium having a liquid temperature range at least partially or substantially above the boiling point of the working fluid may be required.

In some cases, the operating temperature range of CTS and/or HTS media can be changed by pressurizing (i.e., raising the pressure) or evacuating (i.e., lowering the pressure) the thermal media fluid paths and storage tanks, and thus changing the temperature at which the storage media undergo phase transitions.

The HTS medium and/or CTS medium may be in a liquid state over all, or over at least a portion, of the operating temperature range of the respective side of a PHES system. The HTS medium and/or CTS medium may be heated, cooled or maintained to achieve a suitable operating temperature prior to, during or after various modes of operation of a PHES system.

The thermal reservoirs of the PHES systems may cycle between charged and discharged modes, in conjunction with, or separate from, the charge and generation cycles of the overall PHES system embodiment. In some examples, the thermal reservoirs of the PHES systems may be fully charged, partially charged or partially discharged, or fully discharged. In some cases, cold-side thermal reservoir(s) may be charged (also “recharged” herein) independently from hot-side thermal reservoir(s). Further, in some implementations, charging (or some portion thereof) of thermal reservoirs and discharging (or some portion thereof) of thermal reservoirs can occur simultaneously. For example, a first portion of a hot-side thermal reservoir may be recharged while a second portion of the hot-side thermal reservoir together with a cold-side thermal reservoir are being discharged.

Embodiments of the PHES systems may be capable of storing energy for a given amount of time. In some cases, a given amount of energy may be stored for at least about 1 second, at least about 30 seconds, at least about 1 minute, at least about 5 minutes, at least about 30 minutes, at least about 1 hour, at least about 2 hours, at least about 3 hours, at least about 4 hours, at least about 5 hours, at least about 6 hours, at least about 7 hours, at least about 8 hours, at least about 9 hours, at least about 10 hours, at least about 12 hours at least about 14 hours, at least about 16 hours, at least about 18 hours, at least about 20 hours, at least about 22 hours, at least about 24 hours (1 day), at least about 2 days, at least about 4 days, at least about 6 days, at least about 8 days, at least about 10 days, 20 days, 30 days, 60 days, 100 days, 1 year or more.

Embodiments of the PHES systems may be capable of storing/receiving input of, and/or extracting/providing output of, a substantially large amount of energy for use with power generation systems (e.g., intermittent power generation systems such as wind power or solar power), power distribution systems (e.g. electrical grid), and/or other loads or uses in grid-scale or stand-alone settings. During a charge mode of the PHES systems, electric power received from an external power source (e.g., a wind power system, a solar photovoltaic power system, an electrical grid etc.) can be used to operate the PHES systems in the heat pump mode (i.e., transferring heat from a low temperature reservoir to a high temperature reservoir, thus storing energy). During a generation mode of the PHES systems, the system can supply electric power to an external power system or load (e.g., one or more electrical grids connected to one or more loads, a load, such as a factory or a power-intensive process, etc.) by operating in the heat engine mode (i.e., transferring heat from a high temperature reservoir to a low temperature reservoir, thus extracting energy). As described elsewhere herein, during charge and/or generation, the system may receive or reject thermal power, including, but not limited to electromagnetic power (e.g., solar radiation) and thermal power (e.g., sensible energy from a medium heated by solar radiation, heat of combustion etc.).

In some implementations, the PHES systems are grid-synchronous. Synchronization can be achieved by matching speed and frequency of motors and/or generators and/or turbomachinery of a system with the frequency of one or more grid networks with which the PHES systems exchange power. For example, a compressor and a turbine can rotate at a given, fixed speed (e.g., 3600 revolutions per minute (rpm)) that is a multiple of North American grid frequency (e.g., 60 hertz (Hz)). In some cases, such a configuration may eliminate the need for additional power electronics. In some implementations, the turbomachinery and/or the motors and/or generators are not grid synchronous. In such cases, frequency matching can be accomplished through the use of power electronics. In some implementations, the turbomachinery and/or the motors and/or generators are not directly grid synchronous but can be matched through the use of gears and/or a mechanical gearbox. As described in greater detail elsewhere herein, the PHES systems may also be power and/or load rampable. Such capabilities may enable these grid-scale energy storage systems to operate as peaking power plants and/or as a load following power plants. In some cases, the PHES systems of the disclosure may be capable of operating as base load power plants.

Embodiments of the PHES systems can have a given power capacity. In some cases, power capacity during charge may differ from power capacity during discharge. For example, embodiments of the PHES system can have a charge and/or discharge power capacity of less than about 1 megawatt (MW), at least about 1 megawatt, at least about 2 MW, at least about 3 MW, at least about 4 MW, at least about 5 MW, at least about 6 MW, at least about 7 MW, at least about 8 MW, at least about 9 MW, at least about 10 MW, at least about 20 MW, at least about 30 MW, at least about 40 MW, at least about 50 MW, at least about 75 MW, at least about 100 MW, at least about 200 MW, at least about 500 MW, at least about 1 gigawatt (GW), at least about 2 GW, at least about 5 GW, at least about 10 GW, at least about 20 GW, at least about 30 GW, at least about 40 GW, at least about 50 GW, at least about 75 GW, at least about 100 GW, or more.

Embodiments of the PHES systems can have a given energy storage capacity. In one example, a PHES system embodiment may be configured as a 100 MW unit operating for 10-hour cycles. In another example, a PHES system embodiment may be configured as a 1 GW plant operating for 12-hour cycles. In some instances, the energy storage capacity can be less than about 1 megawatt hour (MWh), at least about 1 megawatt hour, at least about 10 MWh, at least about 100 MWh, at least about 1 gigawatt hour (GWh), at least about 5 GWh, at least about 10 GWh, at least about 20 GWh, at least 50 GWh, at least about 100 GWh, at least about 200 GWh, at least about 500 GWh, at least about 700 GWh, at least about 1000 GWh, or more.

In some cases, a given power capacity may be achieved with a given size, configuration and/or operating conditions of the heat engine/heat pump cycle. For example, size of turbomachinery and/or heat exchangers, number of turbomachinery and/or heat exchangers, or other system components, may correspond to a given power capacity.

In some implementations, a given energy storage capacity may be achieved with a given size and/or number of hot-side thermal reservoir(s) and/or cold-side thermal reservoir(s). For example, the heat engine/heat pump cycle can operate at a given power capacity for a given amount of time set by the heat storage capacity of the thermal reservoir(s). The number and/or heat storage capacity of the hot-side thermal reservoir(s) may be different from the number and/or heat storage capacity of the cold-side thermal reservoir(s). The number of thermal reservoir(s) may depend on the size of individual thermal reservoir(s).

Embodiments of the PHES systems may include any suitable number of cold-side and/or hot-side thermal storage units (e.g., CTS medium and/or HTS medium storage tanks, respectively), such as, but not limited to, at least about 1 (divided into two sections), at least about 2, at least about 4, at least about 10, at least about 50, at least about 100, and the like. In some examples, embodiments of the PHES system include 2, 3, 4, 5, 6, 7, 8, 9, 10, 15, 20, 30, 40, 50, 60, 70, 80, 90, 100, or more thermal storage units (e.g., CTS medium and/or HTS medium storage tanks).

While various embodiments of the invention are shown and described herein, it will be obvious to those skilled in the art that such embodiments are provided by way of example only. Numerous variations, changes, and substitutions may occur to those skilled in the art without departing from the invention. It should be understood that various alternatives to the embodiments of the invention described herein may be employed. It shall be understood that different aspects of the invention can be appreciated individually, collectively, or in combination with each other.

It is to be understood that the terminology used herein is used for the purpose of describing specific embodiments, and is not intended to limit the scope of the present invention. It should be noted that as used herein, the singular forms of “a”, “an” and “the” include plural references unless the context clearly dictates otherwise. In addition, unless defined otherwise, all technical and scientific terms used herein have the same meaning as commonly understood by one of ordinary skill in the art to which this invention belongs.

While preferable embodiments of the present invention are shown and described herein, it will be obvious to those skilled in the art that such embodiments are provided by way of example only. Numerous variations, changes, and substitutions will now occur to those skilled in the art without departing from the invention. It should be understood that various alternatives to the embodiments of the invention described herein may be employed in practicing the invention. It is intended that the following claims define the scope of the invention and that methods and structures within the scope of these claims and their equivalents be covered thereby.

The term “reversible,” as used herein, generally refers to a process or operation that can be reversed. In some examples, in a reversible process, the direction of flow of energy is reversible. As an alternative, or in addition to, the general direction of operation of a reversible process (e.g., the direction of fluid flow) can be reversed, such as, e.g., from clockwise to counterclockwise, and vice versa.

The term “sequence,” as used herein, generally refers to elements (e.g., unit operations) in order. Such order can refer to process order, such as, for example, the order in which a fluid flows from one element to another. In an example, a compressor, heat exchange unit, and turbine in sequence includes the compressor upstream of the heat exchange unit, and the heat exchange unit upstream of the turbine. In such a case, a fluid can flow from the compressor to the heat exchange unit and from the heat exchange unit to the turbine. A fluid flowing through unit operations in sequence can flow through the unit operations sequentially. A sequence of elements can include one or more intervening elements. For example, a system comprising a compressor, heat storage unit and turbine in sequence can include an auxiliary tank between the compressor and the heat storage unit. A sequence of elements can be cyclical.

II. Illustrative PHES System

FIG. 2 is a top-level schematic diagram of a PHES system 1000, according to an example embodiment, in which PHES system embodiments herein may be implemented. As a top-level schematic, the example embodiment PHES system 1000 in FIG. 2 illustrates major subsystems and select components, but not all components. Additional components are further illustrated with respect to additional figures detailing various subsystems. Additionally or alternatively, in other embodiments, additional components and/or subsystems may be included, and/or components and/or subsystems may not be included. FIG. 2 further illustrates select components and subsystems that work together in the PHES system 1000. FIG. 2 schematically shows how the select components and subsystems connect, how they are grouped into major subsystems, and select interconnects between them.

In FIG. 2 and FIGS. 3, 3A-3O, 4-9 , connections between subsystems are illustrated as interconnects, such as fluid interconnects 3, 4 and electrical interconnects 15, 21. Illustrated connections between fluid interconnects, electrical interconnects, and/or components reflect fluid paths or power/signal paths, as appropriate. For example, fluid path 901 connects fluid interconnect 2 and fluid interconnect 3, thereby allowing fluid flow between CHX system 600 and AHX system 700, described in further detail below. As another example, power/signal path 902 connects electrical interconnect 15 and electrical interconnect 15A, which can carry power/signals between power interface 2002 and motor system 110. Junctions between illustrated paths are shown as a solid dot. For example, fluid path 903 exiting the main heat exchanger system 300A at fluid interconnect 7 joins the fluid path 904 between fluid interconnect 17 and fluid interconnect 23 at junction 905. Fluid paths may include components, connections, valves, and piping between components, and each fluid path may, in practice, include a single flow path (e.g., a single pipe) or multiple (e.g. parallel) flow paths (e.g., multiple pipes) between components. Valves may interrupt or make fluid connections between various fluid paths, as elsewhere illustrated, such as in FIG. 3 . Valves may be actively controllable through actuators or other known devices in response to control signals, or may change state (e.g., open to close) in response to a physical condition at the valve, such as an overpressure condition at a pressure relief device. Further, valves may include variable position valves (e.g., capable of partial flow such as in proportional or servo valves) or switching valves (e.g., either open or closed). If an illustrated valve is on a fluid path that in practice includes multiple flow paths (e.g., multiple pipes), then each flow path may connect to the single valve or there may be multiple valves connecting the multiple flow paths. For power/signal paths, switches, breakers, or other devices may interrupt or make power/signal connections between various power/signal paths, such as in FIG. 9 .

Major subsystems of PHES system 1000 include a charge powertrain system (“CPT system”) 100, a generation powertrain system (“GPT system”) 200, a working fluid loop 300, a main heat exchanger system 300A, a hot-side thermal storage system (“HTS system”) 501, a cold-side thermal storage system (“CTS system”) 601, and site integration systems 2000.

In FIG. 2 , illustrated components in CPT system 100 include charge motor system 110, charge gearbox system 120, charge compressor system 130, and charge turbine system 140. Depending on operational mode, state, and embodiment configuration, CPT system 100 may connect to other components and subsystems of PHES system 1000 through various interconnects, including electrical interconnect 15 and fluid interconnects 17, 18, 19, and 20. Additionally, CPT system 100 may include more or fewer interconnects than shown in FIG. 2 . The CPT system 100 takes electrical power in at electrical interconnect 15 and converts the electrical energy to working fluid flows through one or more of its fluid interconnects.

In FIG. 2 , illustrated components in GPT system 200 include generation motor system 210, generation gearbox system 220, generation compressor system 230, and generation turbine system 240. Depending on operational mode, state, and embodiment configuration, GPT system 200 may connect to other components and subsystems of PHES system 1000 through various interconnects, including electrical interconnect 21 and fluid interconnects 22, 23, 25, and 26. Additionally, GPT system 200 may include more or fewer interconnects than shown in FIG. 2 . GPT system 200 outputs electrical power at electrical interconnect 21 by taking energy from the working fluid flows through one or more of fluid interconnects. In some operating conditions or states, GPT system 200 may also receive power through one or more of electrical interconnects, such as electrical interconnect 21.

In FIG. 2 , working fluid loop 300 includes a main heat exchanger system 300A, which includes recuperator heat exchanger (“RHX”) system 400, hot-side heat exchanger (“HHX”) system 500, cold-side heat exchanger (“CHX”) system 600, and ambient cooler (heat exchanger) (“AHX”) system 700. Depending on operational mode, state, and embodiment configuration, components in the main heat exchanger system 300A may connect to other components and subsystems of the PHES system 1000, and/or other components within the main heat exchanger system 300A or the working fluid loop 300, through various interconnects, including fluid interconnects 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 28, and 29.

In FIG. 2 , working fluid loop 300 further includes the charge compressor system 130, and charge turbine system 140 of the CPT system 100, and the generation compressor system 230, and generation turbine system 240 of the GPT system 200. Depending on operational mode, state, and embodiment configuration, components in the working fluid loop 300 may connect to other components and subsystems of the PHES system 1000, and/or other components within the working fluid loop 300, through various interconnects, including fluid interconnects 17, 18, 19, 20, 22, 23, 25, and 26.

In the PHES system 1000, working fluid loop 300 may act as a closed fluid path through which the working fluid circulates and in which desired system pressures of the working fluid can be maintained. The working fluid loop 300 provides an interface for the working fluid between the turbomachinery (e.g., charge compressor system 130 and charge turbine system 140, and/or generation compressor system 230 and generation turbine system 240) and the heat exchangers in the main heat exchanger system 300A. In a preferred embodiment, the working fluid is air. Example embodiments, and portions thereof, of working fluid loop 300, are illustrated in FIGS. 3 and 3A-O.

The working fluid loop 300 includes a fluid path that, in some operational modes and/or states of PHES system 1000, carries high-temperature and high-pressure working fluid between charge compressor system 130 and HHX system 500. In other operational modes and/or states a fluid path carries high-temperature and high-pressure working fluid between HHX system 500 and generation turbine system 240. Other configurations are possible as well. These configurations are further detailed with respect to the mode of operation and state descriptions herein and FIGS. 3 and 3A-O.

The working fluid loop 300 includes a fluid path that, in some operational modes and/or states of PHES system 1000, carries medium-temperature and high-pressure working fluid between RHX system 400 and charge turbine system 140. In other operational modes and/or states, a fluid path carries medium-temperature and high-pressure working fluid between generation compressor system 230 and RHX system 400. Other configurations are possible as well. These configurations are further detailed with respect to the mode of operation and state descriptions herein and FIGS. 3 and 3A-O.

The working fluid loop 300 includes a fluid path that, in some operational modes and/or states of PHES system 1000, carries low-temperature and low-pressure working fluid between charge turbine system 140 and CHX system 600. In other operational modes and/or states a fluid path carries low-temperature and low-pressure working fluid between CHX system 600 and generation compressor system 230. Other configurations are possible as well. These configurations are further detailed with respect to the mode of operation and state descriptions herein and FIGS. 3 and 3A-O.

The working fluid loop 300 includes a fluid path that, in some operational modes and/or states of PHES system 1000, carries medium-temperature and low-pressure working fluid between RHX system 400 and charge compressor system 130. In other operational modes and/or states, a fluid path carries medium-temperature and low-pressure working fluid between generation turbine system 240 and RHX system 400. Other configurations are possible as well. These configurations are further detailed with respect to the mode of operation and state descriptions herein and FIGS. 3 and 3A-O.

The main heat exchanger system 300A facilitates heat transfer between the working fluid circulating through the working fluid loop 300, a CTS medium circulating from/to the CTS system 601, an HTX medium circulating from/to the HTS system 501, and the ambient environment or other heat sink via AHX system 700. The CTS medium circulates between a warm CTS system 691 and a cold CTS system 692 via the CHX system 600, and that circulation may be referred to as the “CTS loop” or “cold-side loop,” as further described, e.g., with respect to a CTS system 601 embodiment illustrated in FIG. 5 . In a preferred embodiment, the CTS medium is a coolant fluid, such as a methanol and water mixture. The HTS medium circulates between a warm HTS system 591 and a hot HTS system 592 via the HHX system 500, and that circulation may be referred to as the “HTS loop” or “hot-side loop,” as further described, e.g., with respect to an HTS system 601 embodiment illustrated in FIG. 4 . In a preferred embodiment, the HTX medium is a molten salt.

In FIG. 2 , illustrated components in CTS system 601 include a representation of a cold-side thermal reservoir, including warm CTS system 691 and cold CTS system 692. Depending on operational mode, state, and embodiment configuration, CTS system 601 may connect to other components and subsystems of PHES system 1000 through various interconnects, including fluid interconnects 1 and 31. An example embodiment of CTS system 601, including pumps and supporting fluid paths, valves, and other components is illustrated in FIG. 5 .

In FIG. 2 , illustrated components in HTS system 501 include a representation of a hot-side thermal reservoir, including warm HTS system 591 and hot HTS system 592. Depending on operational mode, state, and embodiment configuration, HTS system 501 may connect to other components and subsystems of PHES system 1000 through various interconnects, including fluid interconnects 6 and 8. An example embodiment of HTS system 501, including pumps and supporting fluid paths, valves, and other components is illustrated in FIG. 4 .

Components in PHES system 1000, including but not limited to valves, fans, sensors, pumps, heaters, heat traces, breakers, VFDs, working fluid compressors, etc., may each be connected to a power source and may be independently controllable, either or both proportionally and/or switchably, via one or more controllers and/or control systems. Additionally, each such component may include, or be communicatively connected via, a signal connection with another such component, through, for example, a wired, optical, or wireless connections. For example, a sensor may transmit data regarding temperature of the working fluid at a location in the working fluid loop; and, a control system may receive that data and responsively send a signal to a valve to close a fluid path. Data transmission and component control via signaling is known in the art and not illustrated herein, except wherein a particular arrangement is new and/or particularly relevant to the disclosed PHES systems, as with, for example, FIG. 9 .

A. Charge Powertrain Subsystem

FIG. 8 is a schematic diagram of the charge powertrain system 100, according to an example embodiment. FIG. 8 provides additional detail concerning CPT system 100 beyond that shown in the top-level schematic of FIG. 2 . The CPT system 100 may be implemented in PHES systems disclosed herein, including the PHES system 1000 embodiment illustrated in FIG. 2 . Other embodiments of a charge powertrain system operable in PHES systems disclosed herein are possible as well.

In FIG. 8 , CPT system 100 includes a motor 110-1 as part of the charge motor system 110 of FIG. 2 , a gearbox 120-1 as part of the charge gearbox system 120 of FIG. 2 , a compressor 130-1 as part of charge compressor system 130, and a turbine 140-1 as part of charge turbine system 140. These components are connected via a drivetrain 150, such that the motor 110-1 is capable of driving the gearbox 120-1, the compressor 130-1, and the turbine 140-1. Drivetrain 150 may include a fixed connection between compressor 130-1 and turbine 140-1, and/or may include one or more shafts, flexible couplings, clutches, and/or gearboxes between compressor 130-1 and turbine 140-1. CPT system 100 further includes a turning motor 121-1 that is additionally capable of driving the compressor 130-1 and/or the turbine 140-1. Within CPT system 100, gearbox 120-1 provides a speed conversion between the motor 110-1 and turning motor 121-1 and the turbomachinery. In other embodiments of a charge powertrain system, the gearbox 120-1 may act only on one of the motors 110-1 and 121-1. Alternatively or additionally, gearbox 120-1 may act only on motor 110-1 and another gearbox (or no gearbox) may act on turning motor 121-1. In another embodiment, gearbox 120-1 may be omitted, therefore resulting in no speed conversion.

Turning motor 121-1 may be used for spinning CPT system 100 turbomachinery at low speeds (e.g., “slow roll”), for example, to cool the compressor 130-1 following a shutdown, and before bringing the rotating equipment to rest. The turning motor 121-1 may be mounted to the gearbox 120-1 or the drivetrain 150 or the motor 110-1, or elsewhere, and preferably rotates the turbomachinery at a very low RPM compared to the motor 110-1. The turning motor 121-1 is fitted with an overrunning clutch 121-2 that disengages when the drivetrain 150 side of the clutch is operating at higher speeds than the turning motor 121-1. This results in the turning motor 121-2 engaging with the drivetrain 150 when the slowing drivetrain 150 reaches the speed of the turning motor 121-1. The turning motor 121-1 will then maintain the slow roll speed.

CPT system 100 can receive power into the subsystem (via, e.g., electrical interconnect 15) and supply power to the motor system 110 (e.g., motor 110-1) and/or the turning motor 121-1. Depending on operational mode, state, and embodiment configuration, and as further illustrated in FIG. 2 , CPT system 100 may receive power via a power interface 2002 and from the generation system 210 and/or an external source such as an electrical grid or local external generation source (e.g., power plant, renewable energy source, etc.) via interconnect 27.

Depending on operational mode and state, compressor 130-1 may raise the pressure of working fluid flowing through the compressor 130-1 by using rotational energy transmitted through the drivetrain 150. For example, during a charging mode (e.g., charge 1002 in FIG. 10 ), compressor 130-1 will compress working fluid flowing through it. As another example, during a slow rolling mode (e.g., CPT slow rolling 1062 in FIG. 15 ), the compressor 130-1, though spinning (e.g., via torque from the turning motor 121-1), may not cause an operationally significant increase in pressure of the working fluid.

Compressor 130-1 has at least one fluid inlet which connects to fluid interconnect 20 and allows working fluid to enter the low-pressure side of the compressor 130-1. Compressor 130-1 also has at least one fluid outlet which connects to fluid interconnect 17 and allows working fluid to exit the high-pressure side of the compressor 130-1. The schematic illustration represented in FIG. 8 is not meant to limit the CPT system 100 to a particular arrangement. For example, the turning motor 121-1 may be oriented differently or located at a different location where it is still capable of turning the drivetrain 150. As another example, inlets and outlets to the turbomachinery may be located at sides other than the top, side, and ends depicted.

A variable frequency drive (“VFD”) (e.g., VFD 214 in FIG. 9 ) may be shared between the CPT system 100 and the GPT system 200. In one embodiment, the VFD may be utilized for startup and slow-rolling of the system only and is configured to exert only positive loads on the drivetrain 150. For example, VFD 214 may provide variable frequency power to motor 110-1 during CPT system 100 spinup.

Depending on operational mode and state, turbine 140-1 may reduce the pressure (e.g., through expansion) of working fluid flowing through the turbine 140-1, and energy derived from that pressure reduction may be transformed into rotational energy in the drivetrain 150. Turbine 140-1 has a fluid inlet which connects to fluid interconnect 18 and allows working fluid to enter the high-pressure side of the turbine 140-1. Turbine 140-1 also has a fluid outlet which connect to fluid interconnect 19 and allows working fluid to exit the low-pressure side of the turbine 140-1.

B. Generation Powertrain Subsystem

FIG. 7 is a schematic diagram of the generation powertrain system 200, according to an example embodiment. FIG. 7 provides additional detail concerning GPT system 200 than is shown in the top-level schematic of FIG. 2 . The GPT system 200 may be implemented in PHES systems disclosed herein, including the PHES system 1000 embodiment illustrated in FIG. 2 . Other embodiments of a generation powertrain system operable in PHES systems disclosed herein are possible as well.

In FIG. 7 , GPT system 200 includes a generator 210-1 as part of the generation system 210 of FIG. 2 , a gearbox 220-1 as part of the generation gearbox system 220 of FIG. 2 , a compressor 230-1 as part of generation compressor system 230, and a turbine 240-1 as part of generation turbine system 240. These components are connected via a drivetrain 250, such that the generator 210-1 is capable of being driven by the gearbox 220-1 and the turbine 240-1, and vice-versa. Depending on operational mode and system states, the generation system 210, and generator 210-1, may generate net positive electrical power that is the sent outside and/or elsewhere within the PHES system 1000. Additionally, depending on the operating condition and state, the generator 210-1 may act as a motor. For example, during spinup of the GPT system 200, the generator 210-1 may receive electrical power and drive the gearbox 220-1 and the turbomachinery. Drivetrain 250 may include a fixed connection between compressor 230-1 and turbine 240-1, and/or may include one or more shafts, flexible couplings, clutches, and/or gearboxes between compressor 230-1 and turbine 240-1.

GPT system 200 further includes a turning motor 221-1 that is capable of driving the compressor 230-1 and the turbine 240-1. Within GPT system 200, gearbox 220-1 provides a speed conversion between the generator 210-1 and turning motor 221-1 and the turbomachinery. In other embodiments of a generation powertrain system, the gearbox 220-1 may act only on one of the generator 210-1 and turning motor 221-1. Alternatively or additionally, gearbox 220-1 may act only on generator 210-1 and another gearbox (or no gearbox) may act on turning motor 221-1. In another embodiment, gearbox 220-1 may be omitted, therefore resulting in no speed conversion

Turning motor 221-1 may be used for spinning GPT system 200 turbomachinery under slow roll, for example, to cool the turbine 240-1 following a shutdown, and before bringing the rotating equipment to rest. The turning motor 221-1 may be mounted to the gearbox 220-1 or the drivetrain 250 or the generator 210-1, or elsewhere, and preferably rotates the turbomachinery at a very low RPM compared to normal operational speed of the turbomachinery. The turning motor 221-1 is fitted with an overrunning clutch 221-2 that disengages when the drivetrain 250 side of the clutch is operating at higher speeds. This results in the turning motor 221-2 engaging with the drivetrain 250 when the slowing drivetrain 250 reaches the speed of the turning motor 221-1. The turning motor 221-1 will then maintain the slow roll speed.

GPT system 200 may send electrical power out of, and receive power into, the subsystem via electrical interconnect 21 and via power interface 2002. Depending on operational mode, state, and embodiment configuration, the power interface 2002 may receive electrical power from the generator 210-1 via electrical interconnect 21A and send electrical power to an external source, such as an electrical grid or other load via electrical interconnect 27. The power interface 2002 may also send electrical power from an electrical grid or other source to GPT system 200. The power interface 2002 may alternatively or additionally route power received from the GPT system 200 to the CPT system 100.

Depending on operational mode and state, compressor 230-1 may raise the pressure of working fluid flowing through the compressor 230-1 by using rotational energy transmitted through the drivetrain 250 from, e.g., the turbine 240-1. For example, during a generation mode (e.g., generation 1004 in FIG. 10 ), compressor 230-1 will compress working fluid flowing through it. As another example, during a slow rolling mode (e.g., GPT slow rolling 1054 in FIG. 14 ), the compressor 230-1, though spinning (e.g., via torque from the turning motor 221-1), may not cause an operationally significant increase in pressure of the working fluid. Compressor 230-1 has a fluid inlet which connects to fluid interconnect 26 and allows working fluid to enter the low-pressure side of the compressor 230-1. Compressor 230-1 also has a fluid outlet which connects to fluid interconnect 22 and allows working fluid to exit the high-pressure side of the compressor 230-1. The schematic illustration represented in FIG. 7 is not meant to limit the GPT system 200 to a particular arrangement. For example, the turning motor 221-1 may be oriented differently or located at a different location where it is still capable of turning the drivetrain 250. As another example, inlets and outlets to the turbomachinery may be located at sides other than the top, side, and ends depicted.

As previously disclosed, a VFD (e.g., VFD 214 in FIG. 9 ) may be shared between the CPT system 100 and the GPT system 200. In one embodiment, the VFD may be utilized for startup and slow-rolling of the system only and is configured to exert only positive loads on the drivetrain 250. For example, VFD 214 may provide variable frequency power to generator 210-1 during GPT system 200 startup.

Depending on operational mode and state, turbine 240-1 may reduce the pressure (e.g., through expansion) of working fluid flowing through the turbine 240-1, and energy derived from that pressure reduction may be transformed into rotational energy in the drivetrain 250. In some modes and states, that rotational energy may be used to rotate the compressor 230-1 and/or generate electrical power at the generator 210-1. Turbine 240-1 has one or more fluid inlets which connect to fluid interconnect 23 and allow working fluid to enter the high-pressure side of the turbine 240-1. Turbine 240-1 also has a fluid outlet which connects to fluid interconnect 25 and allows working fluid to exit the low-pressure side of the turbine 240-1.

C. Site Integration Subsystem

FIG. 9 is a schematic electrical diagram of a power interface, according to an example embodiment, that can be implemented in power interface 2002 in site integration subsystem 2000. Power interface 2000 includes a VFD 214, a VFD-to-generator breaker 211, a generator-to-grid breaker 212, a VFD-to-charge-motor breaker 111, and a charge-motor-to-grid breaker 112, with each component in power interface 2002 electrically connected as illustrated. Breakers can be set to closed or open mode and may be remotely controlled. Other embodiments of a power interface may include additional or fewer breakers, additional or fewer VFDs, different electrical connections, and/or additional components.

For spinning up the GPT system 200, VFD-to-generator breaker 211 can be closed to connect VFD 214 to generation system 210 (e.g., generator 210-1 and/or turning motor 221-1), thus routing power from an external source via electrical interconnect 27, through VFD 214, through breaker 211, and to generation system 210. For generation mode, generator-to-grid breaker 212 can be closed to connect generation system 210 (e.g., generator 210-1) to an external electrical grid or other external load through electrical interconnects 21A and 27. For spinning up the CPT system 100, VFD-to-charge-motor breaker 111 can be closed to connect VFD 214 to the motor system 110 (e.g., motor 110-1 and/or turning motor 121-1) in the CPT system 100 through electrical interconnects 15A and 27. For charge mode, charge-motor-to-grid breaker 112 can be closed to connect motor system 110 (e.g., motor 110-1) in the CPT system 100 to an external electrical grid or other electrical power source through electrical interconnects 15A and 27.

D. Main Heat Exchanger Subsystem

FIGS. 6A and 6B are schematic fluid path diagrams of example embodiments of main heat exchanger systems, that can be implemented as main heat exchanger system in a PHES system (e.g., PHES system 1000). FIGS. 6A and 6B provide additional details, in separate embodiments, concerning main heat exchanger system 300A than is shown in the top-level schematic of FIG. 2 .

The main heat exchanger system 390 embodiment in FIG. 6A and/or the main heat exchanger system 391 embodiment in FIG. 6B can be implemented as the main heat exchanger system 300A in PHES system 1000, or other disclosed PHES systems. Other main heat exchanger system embodiments are also possible. References herein to main heat exchanger system 300A can be understood with reference to embodiments 390 and/or 391.

In general terms, main heat exchanger system 300A consists of four different heat exchanger systems, but all operate together within a PHES system, such as PHES system 1000, to provide the desired operating conditions for operational modes. Each heat exchanger system consists of one or more heat exchanger units that may be connected via manifolds and/or other fluid routing systems.

The main heat exchanger system 300A has two major modes of operation, mirroring the PHES system main modes of operation. During PHES system generation (e.g., generation 1004 in FIG. 10 ), the heat exchangers operate in a forward flow direction at a flow rate between a maximum power (operational maximum) mass flow rate and a maximum turndown (operational minimum) mass flow rate. In this generation mode, heat is transferred from an HTS medium to a working fluid at HHX system 500, from the working fluid to a CTS medium at CHX system 600, from a low-pressure working fluid stream to a high-pressure working fluid stream at RHX system 400, and from the working fluid to the ambient environment or other heat sink at AHX system 700. During PHES system charge (e.g., charge 1002 in FIG. 10 ), the heat exchangers operate in the reverse flow direction at a flow rate between the maximum power mass flow rate and the maximum turndown mass flow rate. In this process, heat is transferred from the working fluid to the HTS medium at HHX system 500, from the CTS medium to the working fluid at CHX system 600, and from a high-pressure working fluid stream to a low-pressure working fluid stream at RHX system 400.

Under some PHES system modes, such as a long term Cold Dry Standby 1010 (see FIG. 10 ), the HTS medium and the CTS medium in the main heat exchanger system 300A is drained to thermal reservoirs (e.g., CTS system 691 and/or 692, and/or HTS system 591 and/or 592). In such a scenario, heat traces may be used to ensure that the HTS medium does not freeze.

Main heat exchanger system 300A includes CHX system 600. A function of CHX system 600 is to transfer heat between a CTS medium and a working fluid. As illustrated in FIGS. 6A and 6B, embodiments of CHX system 600 can include differing amounts of cold-side heat exchangers (“CHX”) depending on design requirements. CHX system 600 is illustrated as including cold-side heat exchangers 600-1, 600-2, through 600-n, which reflect in these example embodiments 390, 391 at least three CHX and can include more than three CHX, although other PHES system embodiments may have less than three CHX. In some embodiments, as illustrated in FIGS. 6A and 6B, each of CHX 600-1 through 600-n is a cross-flow heat exchanger. Specifically, a CTS medium flows through each of CHX 600-1 through 600-n between fluid interconnect 1 and fluid interconnect 13. Additionally, a working fluid flows through each of CHX 600-1 through 600-n between fluid interconnect 2 and fluid interconnect 14. In another embodiment, one or more CHX may not be cross-flow, and may have another internal fluid routing arrangement; however, CTS flow between interconnects 1, 13 and working fluid flow between interconnects 2, 14 is maintained.

As illustrated in FIGS. 6A and 6B, each of CHX 600-1 through 600-n is connected in parallel to the CTS medium and working fluid flows, respectively, with respect to each other CHX. In another embodiment, one or more CHX may be connected in series with one or more CHX. In another embodiment, one more groups of CHX may be connected in parallel, and one or more groups of CHX may be connected in series. In another embodiment, individual CHX and/or groups of CHX may be combined in various combinations of series and parallel configurations.

Main heat exchanger system 300A includes HHX system 500. A function of HHX system 500 is to transfer heat between an HTS medium and a working fluid. Embodiments of HHX system 500 can include differing amounts of hot-side heat exchangers (“HHX”) depending on design requirements. HHX system 500 is illustrated as including hot-side heat exchangers 500-1, 500-2, through 500-n, which reflect in these example embodiments 390, 391 at least three HHX and can include more than three HHX, although other PHES system embodiments may have less than three HHX. In some embodiments, as illustrated in FIGS. 6A and 6B, each of HHX 500-1 through 500-n is a cross-flow heat exchanger. Specifically, an HTS medium flows through each of HHX 500-1 through 500-n between fluid interconnect 6 and fluid interconnect 8. Additionally, a working fluid flows through each of HHX 500-1 through 500-n between fluid interconnect 7 and fluid interconnect 9. In another embodiment, one or more HHX may not be cross-flow, and may have another internal fluid routing arrangement; however, HTS flow between interconnects 6, 8 and working fluid flow between interconnects 7, 9 is maintained.

As illustrated in FIGS. 6A and 6B, each of HHX 500-1 through 500-n is connected in parallel to the HTS medium and working fluid flows, respectively, with respect to each other HHX. In another embodiments, one or more HHX may be connected in series with one or more HHX. In another embodiments, one more groups of HHX may be connected in parallel, and one or more groups of HHX may be connected in series. In another embodiment, individual HHX and/or groups of HHX may be combined in various combinations of series and parallel configurations.

Main heat exchanger system 300A includes RHX system 400. A function of RHX system 400 is to transfer heat between a high-pressure working fluid stream and a low-pressure working fluid stream. Embodiments of RHX system 400 can include differing amounts of recuperator heat exchangers (“RHX”) depending on design requirements. In FIGS. 6A and 6B, RHX system 400 is illustrated as including recuperator heat exchangers 400-1, 400-2, through 400-n, which reflect at least three RHX and can include more than three RHX in these example embodiments, 390, 391 although other PHES system embodiments may have less than three RHX. In some embodiments, as illustrated in FIGS. 6A and 6B, each of RHX 400-1 through 400-n is a cross-flow heat exchanger. Specifically, working flows through each of RHX 400-1 through 400-n between fluid interconnect 5 and fluid interconnect 11. Additionally, the working fluid in a different part of the working fluid loop flows through each of RHX 400-1 through 400-n between fluid interconnect 10 and fluid interconnect 12. In another embodiment, one or more RHX may not be cross-flow, and may have another internal fluid routing arrangement; however, working fluid flow between interconnects 5, 11 and working fluid flow between interconnects 10, 12 is maintained.

As illustrated in FIGS. 6A and 6B, each of RHX 400-1 through 400-n is connected in parallel to the working fluid flows with respect to each other RHX. In another embodiments, one or more RHX may be connected in series with one or more RHX. In another embodiments, one more groups of RHX may be connected in parallel, and one or more groups of RHX may be connected in series. In another embodiment, individual RHX and/or groups of RHX may be combined in various combinations of series and parallel configurations.

Main heat exchanger system 300A includes AHX system 700. A function of AHX system 700 is to transfer heat from a working fluid to the ambient environment, or other external heat sink, during generation mode. In one embodiment, the AHX system 700 will only be operational during PHES system generation (e.g., generation 1004 in FIG. 10 ). For example, during PHES system charge (e.g., charge 1002 in FIG. 10 ), the AHX system 700 will be bypassed, as further discussed herein.

Embodiments of AHX system 700 can include differing configurations and amounts of ambient heat exchangers (“AHX”) (also referred to as ambient coolers) depending on design requirements. In embodiment 390 in FIG. 6A, AHX system 700 is illustrated as including ambient heat exchangers 700-1, 700-2, through 700-n, which reflect at least three AHX in this example embodiment and can include more than three AHX, although other PHES system embodiments may have less than three AHX. In a preferred embodiment, AHX system 700 includes only one AHX, e.g., AHX 700-1. In embodiment 390, as illustrated in FIG. 6A, each of AHX 700-1 through 700-n is an ambient cooler that exhausts heat to the environment from the working fluid flowing through the AHX between fluid interconnects 4 and 3. In the embodiment of FIG. 6A, fluid interconnects 28, 29 are not utilized. In the embodiment of FIG. 6A, individual AHX may include one or more variable-speed fans that can be controlled to adjust ambient air flow across the AHX in order to reach a desired working fluid outlet temperature of the AHX system 700. As illustrated in FIG. 6A, each of AHX 700-1 through 700-n is connected in parallel to the working fluid flow with respect to each other AHX. In another embodiments, one or more AHX may be connected in series with one or more AHX. In another embodiments, one more groups of AHX may be connected in parallel, and one or more groups of AHX may be connected in series. In another embodiment, individual AHX and/or groups of AHX may be combined in various combinations of series and parallel configurations.

In embodiment 391 in FIG. 6B, AHX system 700 is illustrated as including ambient heat exchangers 701-1, 701-2, through 701-n, which reflect at least three AHX in this example embodiment and can include more than three AHX, although other PHES system embodiments may have less than three AHX. In a preferred embodiment, AHX system 700 includes only one AHX, e.g., AHX 701-1. In embodiment 391, as illustrated in FIG. 6B, each of AHX 701-1 through 701-n is a cross-flow heat exchanger. Specifically, a heat sink fluid flows through each of AHX 701-1 through 701-n between fluid interconnect 28 and fluid interconnect 29. Additionally, a working fluid flows through each of AHX 701-1 through 701-n between fluid interconnect 4 and fluid interconnect 3. In the embodiment of FIG. 6B, the heat sink fluid may be ambient air that is pulled from and/or is exhausted to the environment, or the heat sink fluid may be a fluid that is pulled from a heat sink fluid reservoir (not shown) and/or sent to heat sink fluid reservoir (not shown) or other heat sink (not shown), such as a thermal waste heat capture/transfer system. In embodiment 391 of FIG. 6B, heat sink fluid mass flow rate through the AHXs may be adjusted in order to reach a desired working fluid outlet temperature of the AHX system 700. As illustrated in FIG. 6B, each of AHX 701-1 through 701-n is connected in parallel to the working fluid flow with respect to each other AHX. In another embodiments, one or more AHX may be connected in series with one or more AHX. In another embodiments, one more groups of AHX may be connected in parallel, and one or more groups of AHX may be connected in series. In another embodiment, individual AHX and/or groups of AHX may be combined in various combinations of series and parallel configurations.

Main heat exchanger system 300A, as illustrated in embodiment 390 and 391 in FIGS. 6A and 6B, may include heat traces 460 and 560 as part of the RHX system 400 and HHX system 500, respectively. A function of heat trace 460 is to maintain fluid manifolds and/or other metal mass at desired setpoint temperatures during various modes and/or states, for example, in order to reduce thermal gradients on sensitive components. A function of heat trace 560 is to maintain fluid manifolds and/or other metal mass at desired setpoint temperatures during various modes and/or states, for example, in order to avoid freezing (i.e., phase change) of HTX medium in the HHX system 500 and/or to reduce thermal gradients on sensitive components. Each of the heat traces 460 and 560 can function to reduce thermal ramp rates, which benefits heat exchanger longevity, and allows for faster PHES system 1000 startup times. Heat traces 460 and 560 are illustrated as near fluid interconnects 12 and 9, respectively. However, heat traces 460 and 560 can be located at other locations within RHX system 400 and HHX system 500 in order to accomplish their functions. Additionally or alternatively, heat traces 460 and 560 can include heat traces at multiple locations within RHX system 400 and HHX system 500 in order to accomplish their functions.

E. Working Fluid Loop Subsystem

FIG. 3 is a schematic fluid path diagram of a working fluid loop 300 which may be implemented in a PHES system, such as PHES system 1000, according to an example embodiment. FIG. 3 provides additional detail concerning working fluid loop 300 than is shown in the top-level schematic of FIG. 2 . In general terms, the working fluid loop 300 includes, for example, high-pressure fluid paths and low-pressure fluid paths separated by the turbomachinery, turbomachinery bypass and recirculation loops, heat exchangers (e.g., excess heat radiators), valves, pressure relief devices, working fluid supply components (e.g., working fluid compressor), an inventory control system including working fluid tank systems (e.g., high pressure tank systems and low pressure tank systems), and sensors for pressure, temperature, flow rate, dewpoint, speed, and/or fluid concentration. Other embodiments of a working fluid loop operable in PHES systems disclosed herein are possible as well.

FIG. 3N and FIG. 3O illustrate circulatory flow paths of working fluid in working fluid loop 300 for charge mode 1002 and generation mode 1004, respectively. Bold fluid paths illustrate the circulatory flow paths and arrows on bold fluid paths indicate circulatory flow direction. Working fluid may be resident in other fluid paths, but is not actively circulating because such other fluid paths do not form a circulatory circuit with an inlet and outlet (i.e., they are a dead end). Valve positions are indicated with a filled valve icon representing a closed valve, an unfilled valve icon representing an open valve, and a cross-hatched valve representing a valve that may change position state without affecting the illustrated circulatory flow path. For example, in FIG. 3N, valve 231 is closed, valve 131 is open, and valve 242 may change position state without affecting the flow path.

The embodiment of working fluid loop 300 illustrated in FIG. 3 can serve numerous roles within PHES system 1000. The working fluid loop 300 can route working fluid between the turbomachinery and the heat exchangers. The working fluid loop 300 can provide working fluid to the main heat exchanger system 300A for transferring heat between HTS medium and CTS medium during, for example, charge or generation cycles. The working fluid loop 300 can protect the turbomachinery during emergency trip events, and help with compressor surge prevention and overpressure prevention. The working fluid loop 300 can maintain its pressures (e.g., pressures in low-pressure and high-pressure fluid paths) below specified set points for each mode of PHES system operation. The working fluid loop 300 can help with smooth PHES system 1000 startup and shutdown, including, for example, working fluid bypass flow during generation cycle startup to prevent bidirectional loads/demands on a VFD. The working fluid loop 300 can quickly bring working fluid pressures down to allow mode switching operation within short time intervals. The working fluid loop 300 can maintain working fluid loop pressures at or above a minimum working fluid loop base pressure, such as whenever CHX system 600 or HHX system 500 are filled with their respective CTS or HTS media, for example, to prevent leakage of CTS or HTS media into the working fluid loop 300. The working fluid loop 300 can adjust low-side pressure in the working fluid loop between a minimum pressure and working pressures (i.e. pressures during charge and generation), as a means of controlling PHES system power. The working fluid loop 300 can regulate circulate working fluid mass, for example to control PHES system pressures, PHES system power, and/or compensate for working fluid losses from the working fluid loop over time.

The following paragraphs describe components of the working fluid loop 300:

Pressure relief device 101 is a pressure relief device on a low-pressure low-temperature (“LPLT”) portion of the working fluid loop 300. It protects from overpressure the LPLT portion of the working fluid loop in the vicinity, for example, where high-pressure working fluid could be introduced through the turbomachinery, recirculation valves, or bypass valves.

Pressure relief device 102 is a pressure relief device on a low-pressure medium-temperature (“LPMT”) portion of the working fluid loop 300. It protects from overpressure the LPMT portion of the working fluid loop 300 in the vicinity, for example, where high-pressure working fluid could be introduced through the turbomachinery, recirculation valves, and/or bypass valves.

Valve 119 regulates a high-flow recirculation fluid path around compressor system 130 that can be opened, for example, to reduce and/or prevent surge in charge compressor system 130. For example, valve 119 may be opened following a trip event during charge mode operation or when valve 131 is closed. In an embodiment where valve 132 is sufficiently large, valve 119 can be omitted.

Valve 131 is a charge compressor system 130 shutoff valve that, when closed, isolates charge compressor system 130 from the high-pressure side of the working fluid loop 300, for example, during generation mode or following a trip event. Valve 131 preferably fails closed. A benefit of valve 131 is that it can be closed to isolate the compressor system 130 from the large, high-pressure working fluid volume that is present in fluid paths on the side of valve 131 opposite the compressor system 130. That large volume could cause the compressor system 130 (e.g. compressor 130-1) to surge if the compressor system 130 (e.g. compressor 130-1) were to spin down following a power loss or unexpected trip scenario in the PHES system 1000.

Valve 132 regulates a recirculation fluid path around compressor system 130 that can be opened, for example, to recirculate working fluid driven by charge compressor system 130 during, for example, cooldown (e.g., during slow rolling) or after a mode switch. Valve 132 may exhibit slow response time and preferably fails open. A benefit of failing open is that a valve failure does not prevent compressor system 130 cooldown, which is beneficial to prevent damage to the compressor system 130.

Heat exchanger 132H is a radiator in the recirculation fluid path regulated by valve 132 and removes heat (e.g., to ambient) from the working fluid recirculating through charge compressor system 130, for example, following the end of charge mode operation.

Valve 133 is a working fluid dump valve located downstream of the charge compressor system 130 and isolation valve 131. Valve 133 may be, for example, used to reduce the working fluid pressure in the vicinity of the outlet of compressor 130 during certain events, for example trip events during charge mode 1002. Opening valve 133 dumps working fluid to ambient, or a working fluid reservoir (not shown), and decreases working fluid pressure in the vicinity of the outlet of compressor 130, which beneficially reduces the risk of compressor system 130 surge.

Valve 141 is a charge turbine system 140 shutoff valve that, when closed, isolates charge turbine system 140 from the high-pressure side of the working fluid loop 300, for example, during generation mode or following a trip event. Valve 141 preferably fails closed. A benefit of valve 141 is that it can be closed, in conjunction with closing valve 131, to prevent working fluid mass moving from the high-pressure side of the main working fluid loop 300 to the low-pressure side of the working fluid loop 300, which could result in the working fluid loop 300 equilibrating in pressure to a settle-out pressure greater than the pressure rating of components in the low-pressure side of the loop.

Valve 142 regulates a recirculation fluid path around charge turbine system 140 that can be opened, for example, to recirculate working fluid through turbine system 140 during, for example, turning (e.g., slow rolling) or after a mode switch. Valve 142 may exhibit slow response time and preferably fails open. A benefit of valve 142 is that it can be opened to prevent the inlet pressure of the charge turbine system 140 from dropping substantially below the outlet pressure of the turbine system 140 upon closing valve 141, which is beneficial because it prevents the turbine system 140 from operating outside typical design specifications for pressure differentials.

Fan 142F can be operated, when valve 142 is open, to provide recirculation flow of working fluid through the turbine 140 via the recirculation loop controlled by valve 142. This is beneficial, for example, when the spinning turbine system 140 does not create appreciable working fluid flow through the turbine system 140 and consequently experiences windage. Fan 142 can be turned on to create working fluid flow through the turbine system 140 via the recirculation loop to alleviate the windage.

Valve 222 regulates a bypass fluid path that can be opened, for example during generation mode, to provide a working fluid bypass path around the high-pressure side of RHX system 400 and HHX system 500, thereby allowing some amount of working fluid flow through the bypass fluid path instead of through RHX system 400 and HHX system 500. Opening valve 222, preferably in conjunction with closing valves 231 and 241, removes energy (in the form of hot compressed working fluid) that is supplied to the turbine system 240, thereby starving turbine system 240. Beneficially, valve 222 can be opened, for example, when the GPT system 200 experiences a loss of load event (e.g., from the electric grid) or a trip event. Closing valves 231 and 241 and opening of 222 collectively can prevent overspeed of the GPT system 200 as a result of turbine system 240 overspeed.

Valve 229 regulates a bypass fluid path that can be opened to provide a high-flow working fluid bypass path around the high-pressure side of RHX system 400, HHX system 500, and turbine system 240, thereby allowing some amount of working fluid flow through the bypass fluid path instead of through RHX system 400, HHX system 500, and turbine system 240. Beneficially, valve 229 can be opened to reduce load during startup of generation mode and to prevent generation turbine system 240 from generating substantial power during startup of generation mode. Opening valve 229 reduces a net load required of the generator system 210 (e.g., generator 210-1 acting as a motor) during generation mode startup. Opening valve 229 reduces the compressor system 230 power need by reducing outlet pressure at the compressor system 230. Opening valve 229 also starves the turbine system 240 of much of its fluid flow so that the turbine system 240 does not produce substantially more power than the compressor system 230. By keeping a low, but net positive, electrical power demand from generator system 210 (e.g., generator 210-1 acting as a motor) means that a VFD (e.g., VFD 214) supplying power to the generator system 210 can maintain speed control during startup/spin-up. Opening valve 229 also provides a high-flow fluid path to prevent surge in compressor system 230, for example, following a trip event out of generation mode operation and when valve 231 is closed.

Valve 231 is a generation compressor system 230 shutoff valve that, when closed, isolates generation compressor system 230 from the high-pressure side of the working fluid loop during charge mode operation or following a trip event. Valve 231 preferably fails closed. A benefit of valve 231 is that it can be closed to isolate the compressor system 230 from the large high-pressure working fluid volume that is present in fluid paths on the side of valve 231 opposite the compressor system 230. That large volume could cause the compressor system 230 (e.g. compressor 230-1) to surge if the compressor system 230 (e.g. compressor 230-1) were to spin down following a power loss or unexpected trip scenario in the PHES system 1000.

Valve 232 regulates a recirculation fluid path around generation compressor system 230 that can be opened, for example, to recirculate working fluid driven by generation compressor system 230 during, for example, turning or after a mode switch. Valve 232 may exhibit slow response time and preferably fails open. A benefit of valve 232 failing open is that it allows for turbomachinery temperature equilibration upon failure; for example, failure during a during a post-shutdown spinning mode allows cooldown of hot portions of the compressor system 230 and warmup of the inlet side of the compressor system 230.

Valve 241 is generation turbine system 240 shutoff valve that, when closed, isolates generation turbine system 240 from the high-pressure side of the working fluid loop 300 during, for example, charge mode operation or following a trip event. In practical effect, closing valve 241 can starve turbine system 240 and prevent GPT system 200 overspeed. Valve 241 preferably fails closed. A benefit of valve 241 is that can be closed to isolate a source of high-pressure working fluid that could continue to drive the turbine system 240 during, for example, a loss-of-grid-load event, which otherwise might cause an overspeed event for the GPT system 200.

Valve 242 regulates a recirculation fluid path around generation turbine system 240 that can be opened, for example, to recirculate working fluid through turbine system 240 during, for example, cooldown (e.g. during slow rolling) or after a mode switch. Valve 242 may exhibit slow response time and preferably fails open. A benefit of valve 242 failing open is that if valve 242 fails, by failing open it allows for cooldown spinning of GPT system 200 after shutdown of GPT system 200. Cooldown spinning can prevent bowing of rotating components in the turbomachinery. Another benefit of valve 242 failing open is that, when failed open, GPT system 200 can continue to function during generation (e.g., mode 1004) or slow turning (e.g., mode 1006), albeit with decreased efficiency during generation due to open valve 242 creating a bleed path for the working fluid.

Heat exchanger 242H is a radiator in the recirculation fluid path regulated by valve 242 and removes heat (e.g., to ambient) from the working fluid recirculating through turbine system 240.

Fan 242F can be operated, when valve 142 is open, to provide recirculation flow of working fluid through the turbine 240 via the recirculation loop controlled by valve 242. This is beneficial, for example, when the spinning turbine system 240 does not create appreciable working fluid flow through the turbine system 240 and consequently experiences windage. Fan 242 can be turned on to create working fluid flow through the turbine system 240 via the recirculation loop to alleviate the windage and/or for cooling down of turbine system 240 during, for example, slow rolling.

Valve 323 regulates a bypass fluid path that can be opened, for example during charge mode, to provide a working fluid bypass path around AHX system 700, thereby allowing some amount of working fluid flow through the bypass fluid path instead of through AHX system 700. Beneficially, opening valve 323, preferably in conjunction with closing valve 324 (and valve 325 if present), diverts working fluid around AHX system 700, thereby reducing working fluid loop 300 pressure drop when heat dump from the working fluid is not desired, such as during charge mode operation. Valve 323 may exhibit slow actuation time and preferably fails open. Beneficially, valve 323 preferably fails open so that working fluid loop 300 can maintain flow if working fluid valve 324 (and valve 325 if present) is closed or were to fail closed. If valve 323 and valve 324 (or valve 325 if present) are both closed, working fluid circulation in the working fluid loop 300 would stop and the loss of working fluid flow could damage turbomachinery attempting to circulate the working fluid. Additionally, if valve 323 fails open, it allows the PHES system 1000 to continue operating, albeit with a loss of efficiency in some modes. In an alternative embodiment of a working fluid loop, valve 323 may be combined with valve 324, at the junction of the fluid path exiting interconnect 5 and the fluid path entering interconnect 4 in generation mode, as a two-position, three-way valve to accomplish the same effect as the two valves 323, 324.

Valve 324 is an isolation valve that, when closed, isolates AHX system 700 from circulation of working fluid through AHX system 700, for example during charge mode. If valve 325 is present, both valves 324 and 325 may be closed to completely isolate AHX system 700 from working fluid, for example during charge mode and/or service. Valve 324 may exhibit slow actuation time and preferably fails to current position or alternately fails open. Beneficially, if valve 324 fails to current position, the PHES system 1000 can continue its current operation. Alternatively, valve 324 can be specified to fail open for the reasons described above with respect to valve 323.

Valve 325 is an isolation valve that, when closed, isolates AHX system 700 from circulation of working fluid through AHX system 700, for example during charge mode. Valve 325 may exhibit slow actuation time and preferably fails to current position. Beneficially, if valve 325 fails to current position, the PHES system 1000 can continue its current operation. In an alternative embodiment, valve 325 may be omitted from working fluid loop 300. FIGS. 3K, 3L and their corresponding disclosure illustrate that embodiment. In this alternate embodiment with valve 325 omitted, closing valve 324 and opening valve 323 will cause working fluid to not circulate through AHX system 700, and instead bypass AHX system 700 through valve 323. However, omitting valve 325 means that AHX system 700 cannot be fully isolated from the working fluid loop 300, as it will see resident working fluid.

Filter 301 is a working fluid filter (or pre-filter) for working fluid compressor 303 that provides filtration of working fluid entering the working fluid loop 300 from an outside source, such as ambient air when air is the working fluid or for a working fluid that is stored in an outside working fluid make-up reservoir (not shown). Filter 301 may act as a pre-filter if working fluid compressor 303 also contains filters.

Valve 302 is a working fluid compressor 303 feed valve that, when opened, provides the ability for the working fluid compressor 303 to pull working fluid from ambient or an outside working fluid make-up reservoir (not shown). When closed, valve 302 provides the ability for the working fluid compressor 303 to pull working fluid from the working fluid loop 300 (e.g., from evacuation lines via the fluid paths through valve 304 or valve 305).

Working fluid compressor 303 is a make-up working fluid compressor. When activated, working fluid compressor 303 can, depending on valve states, provide working fluid for inventory control system (“ICS”) 300B storage tank systems 310 and/or 320. Additionally or alternatively, when activated, working fluid compressor 303 can, depending on valve states, replenish working fluid loop 300 with working fluid lost through leakage or venting. Additionally or alternatively, when activated, working fluid compressor 303 can, depending on valve states, evacuate working fluid loop 300 to reduce pressure below what ICS 300B valve arrangements can accomplish when lowering the working fluid loop 300 pressure below the settle-out pressure for startup. This is beneficial because working fluid loop 300 is preferably partially evacuated in order to drop working fluid loop 300 pressure when one powertrain (e.g., CPT system 100 or GPT system 200) has spun down and the other power train is spinning up. For example, if PHES system 1000 is coming out of charge mode 1002 and CPT system 100 has just spun down, it is desirable to lower the working fluid loop 300 pressure so that GPT system 200 can start to spin up. “Settle-out” pressure can be interpreted as the resulting pressure in the working fluid loop 300 if working fluid mass were allowed to move from the high-pressure side of the working fluid loop 300 to the low-pressure side of the working fluid loop 300 to the point where the pressure on both sides equilibrated. Additionally or alternatively, when activated, working fluid compressor 303 can, depending on valve states, counteract hysteresis in the functioning of ICS 300B by pumping working fluid mass from the low-pressure side of the working fluid loop 300 to high-pressure tank system 320.

Valve 304 is a feed valve for the working fluid compressor 303 on a low-pressure-side evacuation fluid path of working fluid loop 300. Valve 304, when open, connects the low-pressure side of working fluid loop 300 to working fluid compressor 303 for pulling working fluid from working fluid loop 300 into ICS 300B high-pressure tank system 320.

Valve 305 is a feed valve for the working fluid compressor 303 on a high-pressure-side evacuation fluid path of working fluid loop 300. Valve 305, when open, connects the high-pressure side of working fluid loop 300 to working fluid compressor 303 for pulling working fluid from working fluid loop 300 into ICS 300B high-pressure tank system 320.

Valve 308 is an evacuation valve on the low-pressure side of working fluid loop 300. Valve 308, when open, allows working fluid in the working fluid loop 300 to be evacuated to the environment or an outside working fluid make-up reservoir (not shown). Valve 308 is primarily for servicing of working fluid loop 300, but can also be used for inventory control purposes (e.g., reducing working fluid mass in working fluid loop 300) related to power generation mode 1004, charge mode 1002, or other operations.

Pressure relief device 309 is an ICS 300B low-pressure-side pressure relief device that protects low-pressure fluid paths in working fluid loop 300 from over pressurization, for example, near where high-pressure working fluid is introduced by ICS 300B (e.g., via valve 322) into the low-pressure fluid paths.

Low-pressure tank system 310 is an ICS 300B tank system that includes one or more tanks that store working fluid at low pressure (e.g., less than the pressure in high-pressure tank system 320, and/or less than the pressure in the high-pressure side of working fluid loop 300). Working fluid may be moved into low-pressure tank system 310 from, for example, working fluid loop 300. Working fluid may be released from low-pressure tank system 310 into, for example, working fluid loop 300. Preferably, tank system 310 includes built-in pressure relief devices.

Valve 311 is an ICS 300B HP-LP valve that, for example, when open, allows for release of high-pressure working fluid from the high-pressure side of working fluid loop 300 into the low-pressure tank system 310. Valve 311 may be a controlled proportional valve that is used, for example, for controlling PHES system 1000 power ramping rates.

Valve 312 is an ICS 300B LP-LP valve that, for example, when open, allows for movement of low-pressure working fluid between low-pressure tank system 310 and the low-pressure side of working fluid loop 300.

Valve 314 is an evacuation valve on the high-pressure side of working fluid loop 300. Valve 314, when open, allows working fluid in the working fluid loop 300 to be evacuated to the environment or an outside working fluid make-up reservoir (not shown). Valve 314 is primarily for servicing of working fluid loop 300, but can also be used for inventory control purposes (e.g., reducing working fluid mass in working fluid loop 300) related to power generation mode 1004, charge mode 1002, or other operations.

Valve 318 is a dump valve on the high-pressure side of working fluid loop 300. Valve 318, when open, allows working fluid in the high-pressure side of the working fluid loop 300 to be dumped to the ICS 300B low-pressure tank system 310, lowering pressure in the working fluid loop 300. Beneficially, this preserves filtered working fluid as opposed to evacuating working fluid through valves 308 or 314. Though similarly arranged in ICS 300B, valve 318 may differ from valve 311. Valve 318 may be a fast switched (i.e., “bang-bang”) valve and/or may be larger than valve 318. This is beneficial for moving high-pressure working fluid from the working fluid loop 300 into the low-pressure tank system 310 at a much faster rate than valve 311 can accomplish, which may be preferred for certain mode transitions or trip events.

Pressure relief device 319 is an ICS 300B high-pressure-side pressure relief device that protects high-pressure fluid paths in working fluid loop 300 from over pressurization.

High-pressure tank system 320 is an ICS 300B tank system that includes one or more tanks that store working fluid at high pressure (e.g., higher than the pressure in low-pressure tank system 310, and/or higher than the pressure in the low-pressure side of working fluid loop 300). Working fluid may be moved into high-pressure tank system 320 from, for example, the high-pressure side of working fluid loop 300 via ICS 300B valves (e.g., valve 321) and/or working fluid compressor 303. Working fluid may be released from high-pressure tank system 320 into, for example, the low-pressure side of working fluid loop 300 via ICS 300B valves (e.g., valve 322). Preferably, the high-pressure tank system 320 includes built-in pressure relief devices.

Valve 321 is an ICS 300B HP-HP valve that, for example, when open, allows for movement of high-pressure working fluid between the high-pressure side of working fluid loop 300 and high-pressure tank system 320.

Valve 322 is an ICS 300B LP-HP valve that, for example, when open, allows for release of high-pressure working fluid from high-pressure tank system 320 into the low-pressure side of working fluid loop 300.

Sensors 119S, 130S, 131S, 132S, 140S, 141S, 142S, 229S, 230S, 231S, 232S, 240S, 241S, 242S, 324S, 325S, 361S, 362S, 363S, 364S, 365S, 366S, and 367S are monitoring and reporting devices that can provide one or more of pressure, temperature, flow rate, dewpoint, and/or fluid concentration data to one or more control systems controlling and/or monitoring conditions of the PHES system 1000.

Sensor 303S is a monitoring and reporting devices that can provide one or more of compressor speed, pressure, temperature, and/or flow rate data to one or more control systems controlling and/or monitoring conditions of the PHES system 1000.

Sensors 310S and 320S are monitoring and reporting devices that can provide one or more of pressure, temperature, dewpoint, and/or fluid concentration data to one or more control systems controlling and/or monitoring conditions of the PHES system 1000.

Valve 401 regulates a bypass fluid path that can be opened, for example during generation mode, to provide a working fluid bypass path around the low-pressure side of RHX system 400 and AHX system 700, thereby allowing some amount of working fluid flow through the bypass fluid path instead of through RHX system 400 and AHX system 700. Beneficially, valve 401 may be used in conjunction with valve 222, 323, 324 (and 325, if present) to mitigate a negative effect of opening valve 222. During, for example, generation mode 1004, opening valve 222 (with valves 231, 241 closed), will cause the outlet temperature of turbine system 240 to drop quickly. That results in circulation of colder working fluid downstream of the turbine system 240 that could shock (and potentially damage) the downstream RHX system 400 and AHX system 700 if the colder working fluid were allowed to pass into those heat exchangers. Therefore, as an example, when valve 222 is opened, valve 401 may also be opened and preferably valves 323, 324 (and 325, if present) may be closed, so that the colder working fluid flow from the turbine system 240 outlet bypasses around RHX system 400 and AHX system 700 and flows instead to the inlet of the CHX system 600, which is expecting colder working fluid.

HP/LP Working Fluid Paths

In working fluid loop 300, high-pressure fluid paths are downstream of charge and generation compressor systems 130, 230 and upstream of charge and generation turbine systems 140, 240 (i.e., between outlets of charge and generation compressor systems 130, 230 and inlets of charge and generation turbine systems 140, 240, respectively). Low-pressure fluid paths are downstream of charge and generation turbine systems 140, 240 and upstream of charge and generation compressor systems 130, 230 (i.e., between outlets of charge and generation turbine systems 140, 240 and inlets of charge and generation compressor systems 130, 230, respectively).

For example, a high-pressure fluid path is between the CPT system 100 compressor system 130 outlet and the CPT turbine system 140 inlet. In FIGS. 3 and 3N, that high-pressure fluid path encompasses fluid interconnects 17, 7, 9, 10, 12, and 18. With reference to the circulatory flow paths illustrated in bold in FIG. 3N, the portion of this high-pressure fluid path downstream of compressor system 130, encompassing fluid interconnects 17, 7, 9, 10, and ending at RHX system 400 can additionally be considered a high-pressure high-temperature (e.g., HP-HT) fluid path. Similarly, the portion of this high-pressure fluid path downstream of RHX system 400, encompassing fluid interconnects 12, 18, and ending at the inlet to turbine system 140 can additionally be considered a high-pressure medium-temperature (e.g., HP-MT) fluid path.

Another high-pressure fluid path is between the GPT system 200 compressor system 230 outlet and the GPT turbine system 240 inlet. In FIGS. 3 and 3O, that high-pressure fluid path encompasses fluid interconnects 22, 12, 10, 9, 7, and 23. With reference to the circulatory flow paths illustrated in bold in FIG. 3O, the portion of this high-pressure fluid path downstream of compressor system 230, encompassing fluid interconnects 22, 12, and ending at RHX system 400 can additionally be considered a high-pressure medium-temperature (e.g., HP-MT) fluid path. Similarly, the portion of this high-pressure fluid path downstream of RHX system 400, encompassing fluid interconnects 10, 9, 7, 23, and ending at the inlet to turbine system 240 can additionally be considered a high-pressure high-temperature (e.g., HP-HT) fluid path.

As another example, a low-pressure fluid path is between the CPT system 100 turbine system 140 outlet and the CPT compressor system 130 inlet. In FIGS. 3 and 3N, that low-pressure fluid path encompasses fluid interconnects 19, 14, 2, 5, 11, and 20. With reference to the circulatory flow paths illustrated in bold in FIG. 3N, the portion of this low-pressure fluid path downstream of turbine system 140, encompassing fluid interconnects 19, 14, 2, 5, and ending at RHX system 400 can additionally be considered a low-pressure low-temperature (e.g., LP-LT) fluid path. Similarly, the portion of this low-pressure fluid path downstream of RHX system 400, encompassing fluid interconnects 11, 20, and ending at the inlet to compressor system 130 can additionally be considered a low-pressure low-temperature (e.g., LP-LT) fluid path.

Another low-pressure fluid path is between the GPT system 200 turbine system 240 outlet and the compressor system 230 inlet. In FIGS. 3 and 3O, that low-pressure fluid path encompasses fluid interconnects 25, 11, 5, 4 and 3 (depending on AHX system 700 bypass state), 2, 14, and 26. With reference to the circulatory flow paths illustrated in bold in FIG. 3O, the portion of this low-pressure fluid path downstream of turbine system 240, encompassing fluid interconnects 25, 11, and ending at RHX system 400 can additionally be considered a low-pressure medium-temperature (e.g., LP-MT) fluid path. Similarly, the portion of this low-pressure fluid path downstream of RHX system 400, encompassing fluid interconnects 5, 4 and 3 (depending on AHX system 700 bypass state), 2, 14, 26, and ending at the inlet to compressor system 230 can additionally be considered a low-pressure medium-temperature (e.g., LP-MT) fluid path.

Powertrain Isolation

Valve 131 and valve 141 may be closed to isolate the CPT system 100 turbomachinery during generation mode 1004. Valve 231 and valve 241 may be closed to isolate the GPT system 200 turbomachinery during charge mode 1002. As noted above, these isolation valves 131, 141, 231, 241 are preferably fail-closed valves and preferably they can close quickly to help protect the turbomachinery during a trip event.

AHX System Isolation

The AHX system 700 can exhaust excess heat in the working fluid to the environment. In some embodiments, excess heat may be rejected from the PHES system 1000 via the working fluid loop 300 only during generation (e.g., mode 1004). Excess heat from inefficiency is generated during both charge (e.g. mode 1002) and generation (e.g., mode 1004) due to inefficiencies of the turbomachinery. In an embodiment where excess heat is not rejected during a charge mode (e.g., mode 1002), the excess heat accumulates and results in, for example, a higher CTS medium 690 temperature. In an embodiment where excess heat is rejected during a generation mode (e.g., mode 1004), excess heat from charge mode inefficiency and generation mode inefficiency can be removed from the working fluid loop 300 through the AHX system 700.

Consequently, in a preferred embodiment, it is desirable to provide a mode-switchable working fluid heat dissipation system that can be activated during generation mode 1004 and bypassed during charge mode 1002, or vice versa in another embodiment. In working fluid loop 300, as depicted in FIGS. 3, 3N, 3O, an arrangement of valves allow AHX system 700 to be activated or bypassed depending on the mode (e.g., modes 1002, 1004, or other modes, transitions, or state as further described with respect to, for example, FIG. 11 ). A set of three valves, 323, 324, 325 direct working fluid flow through the AHX system 700 during generation mode, as illustrated in FIG. 3O, and direct working fluid to bypass the AHX system 700 during charge mode, as illustrated in FIG. 3N. To direct working fluid flow through the AHX system 700 during generation mode, valve 323 may be closed and valves 324 and 325 open. Conversely, to bypass AHX system 700, valve 323 may be opened and valves 324 and 325 may be closed. FIGS. 3I and 3J and their corresponding disclosure further illustrate the bypass and active states of AHX system 700. Alternatively, in another embodiment, valve 325 may be omitted and valves 323 and 324 are used to provide a mode-switchable heat dissipation system, as further illustrated and described herein and with respect to FIGS. 3K and 3L.

Inventory Control System

Inventory control refers to control of the mass, and corresponding pressures, of working fluid in the high-pressure and low-pressure sides of working fluid loop 300, which can be controlled to affect, for example, power generation and charge characteristics of the PHES system 1000. Control of working fluid inventory inside working fluid loop 300 can be accomplished with components illustrated in FIG. 3 , and additionally illustrated as ICS 300B in FIG. 3M. One or more controllers, such as illustrated in FIG. 24 , may participate in and/or direct the control. Using inventory control, power of the PHES system 1000 is preferably modulated by adjusting working fluid pressure in the low-pressure side of the working fluid loop 300.

In one example of inventory control, a high-pressure tank system and a low-pressure tank system and associated valves are used to control the amount of working fluid circulating in the working fluid loop 300. High-pressure tank system 320, which may include one or more fluid tanks for holding working fluid, can be connected to a high-pressure working fluid path via valve 321 and to a low-pressure working fluid path via valve 322. Low-pressure tank system 310, which may include one or more fluid tanks, can be connected to a high-pressure working fluid path via valve 311 and to a low-pressure working fluid path via valve 312. The four valves, 311, 312, 321, and 322, may be used to control the direction of working fluid flow between the tank systems 310, 320 and low-pressure or high-pressure fluid paths in the working fluid loop 300, effectively allowing the addition or removal of working fluid circulating through the working fluid loop 300.

ICS 300B further includes a make-up working fluid compressor 303 that can add working fluid to the system. The working fluid loop 300 operates as a closed loop; however, working fluid may be lost over time or intentionally lost due to operational decisions or hardware protection-related operations, such as venting of working fluid in overpressure conditions. Working fluid can be added to the working fluid loop 300 by adding outside working fluid through a working fluid filter 301. To get the outside working fluid into the high-pressure tank system 320, the working fluid compressor 303 is used to pressurize outside working fluid to a pressure greater than the high-pressure tank system 320 (or greater than at least one tank in the high-pressure tank system 320). In an embodiment where the working fluid is air, ambient air may be brought in through the filter 301 and pressurized with the compressor 303. In other embodiments, an outside working fluid make-up reservoir (not shown) may supply working fluid to the filter 301 or the compressor 303.

In another example of inventory control, after a normal shutdown or a trip event in PHES system 1000, pressure in working fluid loop 300 is preferably brought to a lower pressure before either CPT powertrain 100 or GPT powertrain 200 is started. This is beneficial because if high pressure in high-pressure fluid paths of the working fluid loop 300 is not lowered prior to certain mode transitions, the resulting settle-out pressure throughout the working fluid loop 300 would require that low-pressure fluid paths in the working fluid loop 300 be designed to work with a higher pressures than typical operating pressures in the low-pressure fluid paths during charge or generation modes. Thus, if working fluid can be removed from the working fluid loop 300 during spin-down (e.g., transition to hot turning mode 1006 and/or slow rolling state), lower-pressure piping and components can be used in the low-pressure fluid paths of the working fluid loop 300, thus allowing reduced capital investment in the PHES system design. Therefore, it is desirable to bring the circulating working fluid mass down so that the settle-out pressure in the working fluid loop 300 is no more than the typical low-side pressure in the working fluid loop 300.

In one example, working fluid loop 300 pressure reduction can be accomplished by using the working fluid compressor 303 to take working fluid from a high-pressure fluid path via valve 305, or working fluid from a low-pressure fluid path via valve 304, preferably one at a time, and push the working fluid into the high-pressure tank system 320. Additionally or alternatively, valves 311 or 318 can be used to slowly or quickly bleed down pressure from a high-pressure fluid path into the lower pressure tank system 310.

In another example, ICS 300B includes at least one evacuation valve 308 controllable to vent working fluid from the low-pressure side of working fluid loop 300, as well as pressure relief devices throughout the working fluid loop 300 to provide protection from overpressure.

In another example, ICS 300B includes at least one evacuation valve 314 controllable to vent working fluid from the high-pressure side of working fluid loop 300, as well as pressure relief devices throughout the working fluid loop 300 to provide protection from overpressure.

Powertrain Bypass/Recirculation Loops

For each turbomachinery powertrain (e.g., CPT powertrain 100 and GPT powertrain 200), there are working fluid recirculation and bypass loops. A recirculation loop may be characterized as a switchable closed-loop working fluid path that allows recirculation of working fluid from the outlet of a component back to the inlet of the component. For example, a recirculation loop can be used around a compressor system during hot turning. In this example, working fluid is routed from the compressor system outlet back to the compressor inlet instead of through the main heat exchangers, allowing the compressor system to gradually cool down after the compressor system transitions from high flow rate operation (e.g. charge mode 1002 or generation mode 1004) to low flow rate operation (e.g., hot turning mode 1006).

A bypass loop may be characterized as a switchable closed-loop working fluid path that routes working fluid around one or more components in the main working fluid loop 300. For example, during transition from a generation mode 1004 to a trip mode 1012, a bypass loop may be activated during that high flow rate period. The bypass loop could route high flow rate working fluid from a generation compressor system outlet away from the heat exchangers and to a generation turbine system inlet. A bypass loop can be beneficial during trip events (e.g., mode 1012) when surging of the turbomachinery is a risk, and also during turbomachinery startup when it is desirable to reduce startup power.

For the CPT system 100, valve 119, which is normally closed, can open a preferably high flow rate bypass loop around the charge compressor system 130. This is beneficial, for example, to prevent surge in the charge compressor system 130 during a trip event from charge mode.

For the CPT system 100, valve 132, which is normally closed, can open a recirculation loop around the charge compressor system 130. The valve 132 recirculation loop can be activated to allow circulation and also cooling of the working fluid through the heat exchanger 132. The valve 132 recirculation loop may have lower flow rate capability than the valve 119 recirculation loop. The valve 132 recirculation loop can be beneficial, for example, during a hot turning mode for the CPT system 100.

For the CPT system 100, valve 142, which is normally closed, can open a recirculation loop around the charge turbine system 140 to allow recirculation during, for example, hot turning mode for the CPT system 100. As previously noted, fan 142F may assist with working fluid flow in this recirculation loop.

For the GPT system 200, valve 229, which is normally closed, can open a preferably high flow rate bypass fluid path from the outlet of the generation compressor system 230 to the outlet fluid path of the generation turbine system 240 to reduce start-up power at GPT system 200. Routing working fluid through the valve 229 bypass loop reduces the magnitude of power for each of the compressor system 230 and the turbine system 240, and thus reduces the net power magnitude of the GPT system 200. In effect, the valve 229 bypass loop creates a limited starving effect in the GPT system 200. The effect on the turbine system 240 is greater than the effect on the compressor system 230. Consequently, opening the valve 229 bypass loop can keep turbine system 240 power production less than compressor system 230 power draw. Because that ensures a net electrical power input need, generator system 110 must still act as a motor during the duration of spin-up. Beneficially, this maintains VFD control of the spin-up process. As another benefit, opening the valve 229 bypass loop can provide surge protection during a trip event.

For the GPT system 200, valve 232, which is normally closed, can open a recirculation loop around the generation compressor system 230 to provide working fluid circulation through the generation compressor system 230 during, for example, hot turning mode 1006 for the GPT system 200.

For the GPT system 200, valve 242, which is normally closed, can open a recirculation loop around the generation turbine system 240. This recirculation loop can be activated to allow circulation and also cooling of the working fluid recirculating through the heat exchanger 242H, thereby cooling the generation turbine system 240. This is beneficial during, for example, hot turning mode 1006 for the GPT system 200.

For the GPT system 200, valve 222, which is normally closed, can be opened to provide to provide a working fluid bypass path around the high-pressure side of RHX system 400 and HHX system 500. This is further described above with respect to valve 222 and valve 401.

Other recirculation and bypass valves may be implemented in a PHES system, such as PHES system 1000, to provide functionality in surge prevention, overspeed prevention, overpressure prevention, startup load reduction, and low thermal ramping of components.

F. Hot-Side Thermal Storage Subsystem

FIG. 4 is a schematic fluid path diagram of a hot-side thermal storage system which may be implemented in a PHES system, such as PHES system 1000, according to an example embodiment. Other embodiments of an HTS system operable in PHES systems disclosed herein are possible as well. FIG. 4 provides additional detail concerning an HTS system 501 embodiment than is shown in the top-level schematic of FIG. 2 . In general terms, HTS system 501 includes tanks for HTS medium, HTS medium fluid paths, pumps, valves, and heaters. The HTS system 501 is capable of transporting HTS medium 590 back and forth between the two (or more) storage tanks to allow charging of the warm HTS medium 590 (i.e., adding thermal energy) or discharging of the HTS medium 590 (i.e., extracting thermal energy). The heaters are available to ensure that the HTS medium 590 remains in liquid phase for anticipated operational conditions in PHES system 1000.

An HTS system, such as the embodiment of HTS system 501 illustrated in FIG. 4 , can serve numerous roles within a PHES system, such as PHES system 1000. An HTS system may ensure that HTS medium 590 remains in liquid phase during all modes of operation of the PHES system 1000. An HTS system may deliver HTS medium 590 flow to the HHX system 500 to store heat in the HTS medium 590 during charge mode operation of the PHES system 1000 (e.g. mode 1002). An HTS system may deliver HTS medium 590 flow to the HHX system 500 to provide heat from the HTS medium 590 to the working fluid during generation mode operation of the PHES system 1000 (e.g., mode 1004). An HTS system may drain HTS medium 590 from the PHES system 1000 into at least one storage tank. An HTS system may vent entrapped gas in HTS medium 590 fluid paths. An HTS system may protect fluid paths and components from over pressurization. An HTS system may isolate itself from the other PHES 1000 subsystems when the HHX system 500 is disconnected for service, or for thermal rebalancing of the HTS system and/or PHES system 1000. An HTS system may maintain pressure of the HTS medium 590 in the HHX system 500 to be less than that of the working fluid pressure in the working fluid loop 300 at HHX system 500, for example, to prevent leakage of HTS medium into the working fluid loop 300.

In the embodiment of an HTS system shown in FIG. 4 , the HTS system 501 includes two tanks: a warm HTS tank 510 for storing warm HTS medium 590 (e.g., at approximately 270° C.) and a hot HTS tank 520 for storing hot HTS medium 590 (e.g., at approximately 560° C.). In other embodiments, more than one tank may be used to increase the storage capacity of the warm HTS storage 591 and/or the hot HTS storage 592. Each HTS tank 510, 520 has a pump, an immersion heater, and sensors.

In HTS system 501, warm HTS pump 530 circulates HTS medium 590 from warm HTS tank 510, through fluid interconnect 8, through HHX system 500, through fluid interconnect 6, and to the hot HTS tank 520 during PHES charging mode 1002, where the HTS medium 590 is absorbing heat from the working fluid side of the HHX system 500. Hot HTS pump 540 circulates HTS medium 590 from hot HTS tank 520, through fluid interconnect 6, through HHX system 500, through fluid interconnect 8, and to the warm HTS tank 510 during PHES system generation mode 1004, where the HTS medium 590 is providing heat to the working fluid side of the HHX system 500.

In HTS system 501, valves in HTS system 501 can be actuated to bypass the HHX system 500 as necessary in order to isolate HTS tanks 510, 520 from the rest of PHES system 1000 and/or to facilitate thermal balancing of the HTS loop and/or PHES system. The ability to facilitate balancing can be beneficial, for example, to maintain thermal balance between PHES system charge and generation cycles. It is desirable that the mass of HTS medium 590 transferred from warm HTS tank 510 to hot HTS tank 520 during charge (e.g. charge mode 1002) is later transferred back from hot HTS tank 520 to warm HTS tank 510 during generation (e.g., generation mode 1004), and vice versa. However, disturbances to the HTS medium flow rate during charge and generation cycles, resulting from, for example, uneven heat loss across the PHES system 1000, may result in unequal masses of HTS medium 590 transferred between the cycles. If that occurs, direct transfer of HTS medium 590 from warm HTS tank 510 to hot HTS tank 520, or vice versa, may be used to re-balance HTS medium 590 masses at the beginning or end of a charge or generation cycle.

In HTS system 501, valves can be actuated to drain HTS medium 590 in fluid paths, including HHX system 500, into one or more tanks as necessary.

In HTS system 501, heat traces can be used throughout the fluid paths to avoid formation of solid HTS medium 590 during filling of the HTS system 501 and/or during hot turning mode 1006 or hot standby mode 1008 where there may be no significant flow of HTS medium 590 through fluid paths.

The following paragraphs describe components of the HTS system 501:

Warm HTS tank 510 is a tank for storing warm HTS medium 590. In other embodiments, there may be additional warm HTS tanks.

Sensors 510S, 520S are monitoring and reporting devices that can provide temperature and/or fluid level data for HTS medium 590 in tanks 510, 520, respectively, to one or more control systems controlling and/or monitoring conditions in the PHES system 1000.

Valve 511 is a bypass valve that provides a flow path for HTS medium 590 to go directly into the warm tank 510, bypassing the pump 530 when valve 557 is closed.

Heater 512 provides heat to HTS medium 590 in warm HTS tank 510, for example, to ensure it stays in liquid form.

Hot HTS tank 520 is a tank for storing hot HTS medium 590. In other embodiments, there may be additional hot HTS tanks.

Valve 521 is a bypass valve that provides a flow path for HTS medium 590 to go directly into the hot tank 520, bypassing the pump 540 when valve 558 is closed.

Heater 522 provides heat HTS medium 590 in hot tank 520, for example, to ensure it stays in liquid form.

Breather device 529 allows ambient air in and out of the tank head space as the HTS medium 590 expands and contracts with temperature.

Warm HTS pump 530 delivers HTS medium 590 from warm HTS tank 510 to hot HTS tank 520 via HHX system 500 during charge mode operation. Depending on valve state, pump 530 can alternatively or additionally deliver HTS medium 590 to hot HTS tank 520 via bypass valve 551, bypassing HHX system 500, for balancing purposes. In other embodiments, there may be additional warm HTS pumps.

Hot HTS pump 540 delivers HTS medium 590 from hot HTS tank 520 to warm HTS tank 510 via HHX system 500 during generation mode operation. Depending on valve state, pump 540 can alternatively or additionally deliver HTS medium 590 to warm HTS tank 510 via valve 551, bypassing HHX system 500, for balancing purposes. In other embodiments, there may be additional hot HTS pumps.

Valve 551 is an HHX system 500 bypass valve that provides a fluid flow path allowing HTS medium 590 to travel between HTS tanks 510, 520 while bypassing HHX system 500.

Sensors 5515, 552S are monitoring and reporting devices that can provide temperature, flow, and/or pressure data to one or more control systems controlling and/or monitoring conditions in the PHES system 1000.

Valve 552 is a drain valve that provides a fluid flow path for draining of HTS medium 590 into or out of warm tank 510.

Valve 553 is a drain valve that provides a fluid flow path for draining of HTS medium 590 into or out of hot tank 520.

Valve 554 is a check valve that works as a gas release valve to allow accumulated gas in the HTS system 501 to migrate to a tank cover gas space in either or both tanks 510, 520.

Valve 555 is an HHX system 500 isolation valve that restricts HTS medium 590 flow between the HHX system 500 and HTS system 501 through interconnect 8.

Valve 556 is an HHX system 500 isolation valve that restricts HTS medium 590 flow between the HHX system 500 and HTS system 501 through interconnect 6.

Valves 552, 553, 555, and 556 can all be closed to isolate HHX system 500 from HTS medium 590 in the HTS system 501.

Valve 557 is a warm CTS pump 530 outlet valve that can be opened to allow CTS medium 590 flow from warm CTS pump 530 or closed to prevent flow into the outlet of hot CTS pump 530.

Valve 558 is a hot CTS pump 540 outlet valve that can be opened to allow CTS medium 590 flow from hot CTS pump 540 or closed to prevent flow into the outlet of hot CTS pump 540.

Heat trace 560 can be activated to maintain fluid paths and/or other metal mass at temperatures sufficient to keep the HTS medium 590 in liquid phase, and/or at desired setpoint temperatures during various modes and/or states of PHES system 1000 in order to reduce thermal gradients on sensitive components, and/or to reduce transition time between PHES system 1000 modes and states. Beneficially, heat trace 560 can reduce thermal ramp rates, which benefits component longevity, and allows for faster startup times. Heat trace 560 is illustrated as near fluid interconnect 8 and on the warm tank 510 side of HTS system 501. However, heat trace 560 can be located at other locations within HTS system 501 in order to accomplish its functions. Additionally or alternatively, heat trace 560 can include heat traces at multiple locations within HTS system 501 in order to accomplish its functions.

Operation of HTS System

During PHES system 1000 generation mode 1004, the HTS system 501 is configured such that hot HTS medium 590 is delivered from hot HTS tank 520 to warm HTS tank 510 via HHX system 500 at a fixed and/or controllable rate using pump 540. During generation, heat from the hot HTS medium 590 is transferred to the working fluid via the HHX system 500. The rated generation flow of HTS medium 590 at a given PHES system 1000 power may be a function of the generation flow of CTS medium 690 to maintain inventory balance.

During PHES system 1000 charge mode 1002, the HTS system 501 is configured such that warm HTS medium 590 can be delivered from warm HTS tank 510 to hot HTS tank 520 via HHX system 500 at a fixed or controllable rate using the pump 530. During charge, the warm HTS medium 590 absorbs heat from the hot working fluid via the HHX system 500. The rated charge flow of HTS medium 590 at a given PHES system 1000 power may be a function of the charge flow of CTS medium 690 to maintain inventory balance.

Under some PHES system 1000 modes, such as long-term Cold Dry Standby, the HTS medium 590 in the hot-side loop (e.g., HTS system 501, HHX system 500, and intermediate fluid paths) needs to be drained to the HTS tanks 510 and/or 520. In this scenario, preferably the heater 512 in the warm tank 510 is used to ensure HTS medium 590 remain in liquid form. Preferably, for example, the hot HTS pump 540 can be used to transfer hot HTS medium 590 from the hot HTS tank 520 to the warm HTS tank 510 via the HHX system 500 bypass line (e.g., via valve 551) and valve 511. Alternatively, warm HTS pump 530 can be used to transfer warm HTS medium 590 from the warm HTS tank 510 to the hot HTS tank 520 via the HHX system 500 bypass line (e.g., via valve 551) and valve 521. HTS 590 medium remaining in hot HTS tank 520 may also be kept in a liquid state with heater 522.

Under certain operating modes, HHX system 500 can be bypassed by closing valves 552, 553, 555, and 556, opening valve 551, and using pump 530 or 540 to cause flow of HTS medium 590 between HTS tanks 510 and 520 For example, HHX system 500 can be bypassed to balance the thermal energy content either between the HTS tanks 510, 520 individually and/or to balance total thermal energy between HTS system 501 and CTS system 601.

G. Cold-Side Thermal Storage Subsystem

FIG. 5 is a schematic fluid path diagram of a cold-side thermal storage system which may be implemented in a PHES system, such as PHES system 1000, according to an example embodiment. Other embodiments of an CTS system operable in PHES systems disclosed herein are possible as well. FIG. 5 provides additional detail concerning a CTS system 601 embodiment than is shown in the top-level schematic of FIG. 2 . In general terms, CTS system 601 includes tanks for CTS medium, CTS medium fluid paths, pumps, valves, and inert gas supply. The CTS system 601 is capable of transporting CTS medium 690 back and forth between the two (or more) storage tanks to allow charging of the CTS medium 690 (i.e., removing thermal energy) or discharging of the CTS medium 690 (i.e., adding thermal energy). During PHES system 1000 charge mode operation, the CTS medium 690 deposits heat to working fluid inside the CHX system 600. During PHES system 1000 generation mode operation, the CTS medium 690 absorbs heat from the working fluid inside the CHX system 600.

A CTS system, such as CTS system 601 illustrated in FIG. 5 , can serve numerous roles within a PHES system, such as PHES system 1000. A CTS system may deliver CTS medium 690 flow to the CHX system 600 to provide heat during charge mode operation of PHES system 1000 (e.g., mode 1002). A CTS system may deliver CTS medium 690 flow to the CHX system 600 to absorb heat during generation mode operation of the PHES system 1000 (e.g., mode 1004). A CTS system may drain CTS medium 690 into at least one storage tank. A CTS system may vent entrapped gas in CTS medium 690 fluid paths. A CTS system may protect fluid paths and components from over pressurization. A CTS system 601 may isolate itself from other PHES 1000 subsystems when the CHX system 600 is disconnected for service, or for thermal rebalancing. A CTS system may isolate the CTS medium 690 from ambient via an inert gas blanket. A CTS system may maintain pressure of the CTS medium 690 in the CHX system 600 to be less than that of the working fluid pressure in the working fluid loop 300 at CHX system 600, for example, to prevent leakage of CTS medium into the working fluid loop 300. A CTS system 601 may monitor CTS medium 690 health during operation.

In the embodiment of a CTS system shown in FIG. 5 , the CTS system 601 includes two tanks: a warm CTS tank 610 for storing warm CTS medium 690 (e.g., at approximately 30° C.) and a cold CTS tank 620 for storing cold CTS medium 690 (e.g., at approximately −60° C.). In other embodiments, more than one CTS tank may be used to increase the storage capacity of the warm CTS storage 691 and/or the cold CTS storage 692. In CTS system 601, each CTS storage 691, 692 has a pump system 639, 649, respectively.

In CTS system 601, warm pump 630 circulates CTS medium 690 from warm CTS tank 610, through fluid interconnect 1, through CHX system 600, through fluid interconnect 13, and to the cold CTS tank 620 during PHES 1000 charging mode 1002, where the CTS medium 690 is providing heat to the working fluid side of the CHX system 600. The cold pump 640 circulates CTS medium 690 from cold CTS tank 620, through fluid interconnect 13, through CHX system 600, through fluid interconnect 1, and to the warm CTS tank 610 during PHES system 1000 generation mode 1004, where the CTS medium 690 is absorbing heat from the working fluid side of the CHX system 600.

Valves in CTS system 601 can be actuated to bypass the CHX system 600 as necessary in order to isolate CTS storage 691, 692 from the rest of PHES system 1000 and/or to facilitate balancing of the CTS loop. The ability to facilitate balancing can be beneficial, for example, to maintain thermal balance between PHES system charge and generation cycles. It is desirable that the mass of CTS medium 690 transferred from warm CTS tank 610 to cold CTS tank 620 during charge (e.g. charge mode 1002) is later transferred back from cold CTS tank 620 to warm CTS tank 610 during generation (e.g., generation mode 1004). However, disturbances to the CTS flow rate during charge and generation cycles, resulting from, for example uneven heat loss across the PHES system 1000, may result in unequal masses of CTS medium 690 transferred between the cycles. If that occurs, direct transfer of CTS medium 690 from warm CTS tank 610 to cold CTS tank 620, or vice versa, may be used to re-balance CTS medium 690 masses at the beginning or end of a charge or generation cycle.

In CTS system 601, valves can be actuated to drain CTS medium 690 in fluid paths, including CHX system 600, into one or more tanks as necessary.

In an embodiment of CTS system 601, one, or both of, CTS pumps 630, 640 are capable of bidirectional flow. Beneficially, reverse pumping can be used to provide active pressure reduction in the CTS loop, which can be employed to keep CTS medium 690 pressure in CHX system 600 below working fluid pressure in CHX system 600. This working fluid positive pressure condition (with respect to CTS medium 690) beneficially prevents any CTS medium from leaking into the working fluid loop 300 (e.g., through cracked heat exchanger cores).

The following paragraphs describe components of the CTS system 601:

Valve 602 is a CHX system 600 isolation valve that restricts CTS medium 690 flow between the CHX system 600 and CTS system 601 through interconnect 13.

Valve 603 is a CHX system 600 isolation valve that restricts CTS medium 690 flow between the CHX system 600 and CTS system 601 through interconnect 1.

Valves 602, 603 can both be closed to isolate the CHX system 600 from CTS medium 690 in the CTS system 601.

Valve 605 is a CHX system 600 bypass valve that provides a fluid flow path allowing CTS medium 690 to travel between CTS tanks 610, 620 while bypassing CHX system 600.

Warm CTS tank 610 is a tank for storing warm CTS medium 690.

Sensors 610S, 620S are monitoring and reporting devices that can provide temperature and/or fluid level data for HTS medium 690 in tanks 610, 620, respectively, to one or more control systems controlling and/or monitoring conditions in the PHES system 1000.

Valve 611 is an isolation valve that isolates warm CTS tank 610 from the CTS loop.

Pressure relief device 619 protects CTS tanks 610, 620 from over pressurization via a gas fluid path between the headspace of CTS tanks 610, 620.

Cold CTS tank 620 is a tank for storing cold CTS medium 690.

Valve 621 is an isolation valve that isolates cold CTS tank 620 from the CTS loop.

Inert gas reservoir 622 is a storage reservoir for an inert gas (e.g., nitrogen) useable as a cover gas to blanket CTS medium 690 in tanks 610, 620.

Valve 623 is an inert gas fluid path valve that can control a flow of inert gas from inert gas reservoir 622 to the headspace of CTS tanks 620, 621 which are connected via a gas fluid path. Valve 623 can be used to regulate the pressure of an inert gas blanket within the CTS tanks 610, 620.

Valve 624 is an inert gas purge valve that can control a flow of pressurized inert gas into the cold-side loop CTS medium 690 fluid paths to purge those fluid paths of CTS medium 690.

Warm CTS pump 630 delivers CTS medium 690 from warm CTS tank 610 to cold CTS tank 620 via CHX system 600 during charge mode operation of the PHES system 1000 (e.g., mode 1002). Depending on valve states, pump 630 can alternatively or additionally deliver CTS medium 690 to cold CTS tank 620 via valve 605, bypassing CHX system 600, for balancing purposes. In other embodiments, there may be additional warm CTS pumps.

Valve 631 is a warm pump 630 isolation valve that, when closed, can isolate pump 630, for example during PHES system 1000 generation mode when CTS medium 690 is flowing from cold CTS tank 620 to warm CTS tank 610. In an embodiment where pump 630 is bidirectional and operating in reverse, valve 631 may be open during generation mode to allow active pressure reduction in the CTS loop.

Valve 632 is a warm CTS pump 630 bypass valve that provides a flow path around pump 630 during, for example, generation mode operation of the PHES system 1000 (e.g., mode 1004) or balancing of CTS medium 690 in CTS system 601.

Valve 633 is a warm pump 630 isolation valve that, when closed along with warm pump outlet valve 631, allows for servicing of warm pump 630 when the pump is not in use, for example during PHES system 1000 generation mode when CTS medium 690 is flowing to warm tank 610 through pump 630 bypass valve 632.

Warm CTS pump system 639 and cold CTS pump system 649 illustrate respective CTS medium 690 pumping systems for warm CTS storage 691 and cold CTS storage 692, respectively.

Cold pump 640 delivers CTS medium 690 from cold CTS tank 620 to warm CTS tank 610 via CHX system 600 during generation mode operation of the PHES system 1000 (e.g., mode 1004). Depending on valve state, pump 640 can alternatively or additionally deliver CTS medium 690 to warm CTS tank 620 via valve 605, bypassing CHX system 600, for balancing purposes. In other embodiments, there may be additional cold CTS pumps.

Valve 641 is a cold pump 640 isolation valve that, when closed, can isolate pump 640, for example during PHES system 1000 charge mode when CTS medium 690 is flowing from warm CTS tank 610 to cold CTS tank 620. In an embodiment where pump 640 is bidirectional and operating in reverse, valve 641 may be open during generation mode to allow active pressure reduction in the CTS loop.

Valve 642 is a cold CTS pump 640 bypass valve that provides a flow path around pump 640 during, for example, charge mode operation of the PHES system 1000 (e.g., mode 1002) or balancing of CTS medium 690 in CTS system 601.

Valve 643 is a cold pump 640 isolation valve that, when closed along with cold pump outlet valve 641, allows for servicing of cold pump 640 when the pump is not in use, for example during PHES system 1000 charge mode when CTS medium 690 may be flowing to cold tank 620 through pump 640 bypass valve 642.

Sensors 661S, 662S, 663S, 664S, 665S, 666S, 667S, 668S are monitoring and reporting devices that can provide temperature, flow, and/or pressure data to one or more control systems controlling and/or monitoring conditions in the PHES system 1000.

Valve 682 is a check-style vent valve that allows entrapped CTS medium 690 gas in CTS loop fluid paths (e.g., CTS system 601 and CHX system 600) to be vented to a cover gas region of the CTS tanks 610, 620, but prevents gas or fluid from the CTS tanks from flowing back towards CHX system 600.

Operation of CTS System

During PHES system 1000 charge mode 1002, warm pump 630 delivers warm CTS medium 690 at a fixed or controllable rate from warm CTS tank 610 to cold CTS tank 620 via CHX system 600. During charge, heat from the warm CTS medium 690 is transferred to the working fluid via the CHX system 600. The rated charge flow of CTS medium 690 at a given PHES system 1000 power may be a function of the charge flow of HTS medium 590 to maintain inventory balance. The cold CTS pump 640 can be used to reduce pressure at the CHX system 600 by pulling CTS medium 690 from there.

During PHES system 1000 generation mode 1004, the cold pump 640 delivers cold CTS medium 690 at a fixed or controllable rate from the cold CTS tank 620 to the warm CTS tank 610 through CHX system 600. The rated generation flow of CTS medium 690 at a given PHES system 1000 power may be a function of the generation flow of HTS medium 590 to maintain inventory balance. The warm coolant pump 630 can be used to reduce pressure at the CHX system 600 by pulling CTS medium 690 from there.

Under some PHES system 100 modes, such as long-term Cold Dry Standby, the CTS medium 690 in the cold-side loop (e.g., CTS system 601, CHX system 600, and intermediate fluid paths) needs to be drained to the CTS tanks 610 and/or 620. For example, cold pump 640 can be used to transfer cold CTS medium 690 in the cold tank 620 to the warm tank 610 via a fluid path through bypass valve 605.

Under certain operating modes, CHX system 600 can be bypassed by closing valves 602, 603 and opening valve 605, and using pumps 630 and/or 640 to cause flow of CTS medium 690 between CTS tanks 610 and 620. For example, CHX system 600 can be bypassed to balance the thermal energy content either between CTS tanks 610, 620 individually and/or to balance total thermal energy between CTS system 601 and HTS system 501.

III. Operating Modes and States in a PHES System

Disclosed herein are various modes of operation and states of a PHES system, each of which may be implemented in the exemplary PHES system 1000.

A. Primary Modes of Operation

The PHES systems herein, including PHES system 1000, can transition through a number of modes of operation. Each of the primary modes of operation can be described with respect to a particular state of components and subsystems in the PHES system. Additionally, each of the primary modes of operation has an associated active parasitic load and a readiness time. Example primary modes of operation of the disclosed PHES systems are shown in FIG. 10 .

FIG. 10 illustrates primary modes of operation of a PHES system, including PHES system 1000, according to an example embodiment. The primary modes of operation include charge 1002, generation 1004, hot turning 1006, hot standby 1008, cold dry standby 1010, and tripped 1012. FIG. 10 further illustrates the preferred transitions between modes, as indicated by directional arrows between modes. For example, in one embodiment, a PHES system, such as PHES system 1000, can transition from charge 1002 to hot turning 1006 to hot standby 1008 to cold dry standby 1010. In another example, a PHES system, such as PHES system 1000, can transition from charge 1002 to hot turning 1006 to generation 1004.

Cold Dry Standby Mode 1010. In this primary mode of operation, the thermal storage reservoirs are effectively offline and the associated thermal storage media are at their lowest practical thermal energy state for a given embodiment. In embodiments with liquid thermal storage, the thermal storage media may be drained to their respective tanks and not circulated through the rest of the PHES system. In embodiments with a hot-side liquid thermal storage media (e.g., molten salt), the hot-side liquid thermal storage media may be kept at a minimum temperature to prevent freezing, which may include active heating to maintain this minimum practical thermal energy state. In embodiments with a coolant as a cold-side liquid thermal storage media, the coolant may be kept at or near environmental ambient temperature. In some embodiments, the remainder of the PHES system infrastructure may also be kept at or near environmental ambient temperature. In some embodiments, pressure in the working fluid loop may be kept at or near ambient environmental pressure or at a minimum working fluid pressure P_(standby). In one embodiment, P_(standby) is a pressure in the working fluid loop (e.g., working fluid loop 300) below working pressure (e.g., during charge or generation modes 1002, 1004) but still sufficient to ensure positive pressure with respect to any opposite side pressure in HTS medium or CTS medium heat exchanger systems (e.g., HHX system 501 or CHX system 601). Maintaining P_(standby) beneficially prevents any HTS medium or CTS medium from leaking into the working fluid loop (e.g., through cracked heat exchanger cores).

In Cold Dry Standby mode 1010, a PHES system achieves its lowest active parasitic load. In some embodiments, there is no significant parasitic load. In some embodiments, heating a hot-side liquid thermal storage media to prevent freezing is an active parasitic load. In some embodiments, maintaining a working fluid pressure at P_(standby) greater than ambient environmental pressure is an active parasitic load.

Within embodiments of the disclosed PHES systems, including PHES system 1000, the readiness time to transition between cold dry standby mode 1010 and either charge mode 1002 or generation mode 1004 (via hot standby mode 1008) is a relatively long time compared to other mode transitions to charge mode 1002 or generation mode 1004.

Hot Standby Mode 1008. In this primary mode of operation, heat exchangers are primed with thermal storage media. In some embodiments, hot-side and/or cold-side heat exchangers are filled partially or completely with HTS and/or CTS media, respectively. In the case of liquid thermal storage media, the thermal storage media may or may not be continuously flowing through the heat exchangers, preferably at a very low flow rate. One or more hot-side heat exchangers (e.g., HHX system 500) are warmed above ambient environmental temperature. In some embodiments, heat traces or other heaters (e.g., heaters 512, 522) are used to heat the HTS medium, which in turn warms the hot-side heat exchanger(s). The warmed hot-side heat exchangers may be at or near their steady-state temperature for charge or generation modes, or may be at an intermediate temperature between their steady-state temperature and ambient environmental temperature. CPT system (e.g., CPT system 100) and GPT system (e.g., GPT system 200) are at zero RPM or substantially zero RPM (e.g., no turning, temporarily spinning down to eventual zero RPM from a prior state, insubstantial turning as a result of convective currents only, and/or no torque input from motors). In some embodiments, minimum pressure in the working fluid loop is kept at P_(standby), though pressure in the working fluid loop (e.g. working fluid loop 300) may be higher initially upon entering hot standby mode 1008, depending on the prior mode the PHES system is transitioning from.

In hot standby mode, embodiments of the disclosed PHES systems can experience active parasitic load from heaters working on the thermal storage media. In some embodiments, heat traces are active to keep the thermal storage media at or near steady-state temperatures. In some embodiments, maintaining a working fluid pressure at P_(standby) is an active parasitic load.

Within embodiments of the disclosed PHES systems, including PHES system 1000, and beneficially, the readiness time to transition between hot standby mode 1008 and either charge mode 1002 or generation mode 1004 is relatively short. For example, the readiness time may be less than 10% of the readiness time for transition from cold dry standby mode 1010 to either charge mode 1002 or generation mode 1004.

Hot Turning Mode 1006. In this primary mode of operation, either or both the CPT system and/or GPT system is slow rolling (i.e., CPT and/or GPT turbomachinery is spinning at a minimum speed). In a preferred embodiment, the slow-rolling turbomachinery use recirculation and/or bypass fluid loops, such as the examples disclosed herein, to circulate working fluid through the slow-rolling turbomachinery.

Within embodiments of the disclosed PHES systems, including PHES system 1000, and beneficially, the readiness time to transition between hot turning mode 1006 and either charge mode 1002 or generation mode 1004 is shorter than the readiness time to transition between hot standby mode 1008 and either charge mode 1002 or generation mode 1004.

Charge Mode 1002. In this primary mode of operation, the CPT system turbomachinery is connected to the electrical grid and preferably operating at grid speed, i.e., the CPT system is operating at an RPM that synchronizes the motor system with the operating frequency of the connected electrical grid. In some embodiments, the GPT system is at zero RPM or substantially zero RPM (e.g., no turning, temporarily spinning down to eventual zero RPM from prior state, insubstantial turning as a result of convective currents only, and/or no torque input from motors). In some embodiments, the GPT system is at turning speed. In charge mode, thermal storage media are substantially at steady-state temperatures and one or more control systems control may modulate power consumption of the disclosed PHES systems by, for example, controlling the pressure of the working fluid. In another embodiment, one or more control systems may control CTS medium and/or HTS medium flow rates and/or pressures through the main heat exchanger system to modulate power consumption of the disclosed PHES systems. In another embodiment, one or more control systems control both the pressure of the working fluid and/or CTS medium and/or HTS medium flow rates and/or pressures to modulate power consumption of the disclosed PHES systems.

In charge mode, active parasitic loads include support systems for the heat exchanger systems and any associated fluid loops, support systems for CPT system, and in some embodiments, support systems for the GPT system if the generation powertrain is turning.

Beneficially, embodiments of the disclosed PHES systems can ramp the charge mode 1002 power consumption very quickly between full power and a significantly reduced power consumption level (and vice versa). Additionally, within embodiments of the disclosed PHES systems, including PHES system 1000, and beneficially, the readiness time to transition between charge mode 1002 and generation mode 1004 (or vice versa) via hot turning mode 1006 is shorter than the readiness time to transition between hot standby mode 1008 and either charge mode 1002 or generation mode 1004.

Generation Mode 1004. In this primary mode of operation, the GPT system is connected to the electrical grid and preferably operating at grid speed, i.e., the GPT system is operating at an RPM that synchronizes the generator system with the operating frequency of the connected electrical grid. In some embodiments, the charge powertrain is at zero RPM or substantially zero RPM (e.g., no turning, temporarily spinning down to eventual zero RPM from prior state, insubstantial turning as a result of convective currents only, and/or no torque input from motors). In some embodiments, the CPT system is at turning speed. In generation mode, thermal storage media are substantially at steady-state temperatures. In generation mode, thermal storage media are substantially at steady-state temperatures and one or more control systems control may modulate power generation of the disclosed PHES systems by, for example, controlling the pressure of the working fluid. In another embodiment, one or more control systems may control CTS medium and/or HTS medium flow rates and/or pressures through the main heat exchanger system to modulate power generation of the disclosed PHES systems. In another embodiment, one or more control systems control both the pressure of the working fluid and/or CTS medium and/or HTS medium flow rates and/or pressures to modulate power generation of the disclosed PHES systems.

In generation mode, active parasitic loads include support systems for the heat exchanger systems and any associated fluid loops, support systems for GPT system, and in some embodiments, support systems for the CPT system if the charge powertrain is turning.

Beneficially, embodiments of the disclosed PHES systems can ramp the generation mode 1004 power generation very quickly between low power and full power (and vice versa).

Tripped Mode 1012. This primary mode of operation is a state of recovery from a trip event. This mode may include spin-down of one or more of the powertrains (e.g. CPT system 100, GPT system 200) from its prior controlled (e.g., hot turning and/or steady-state) speed to a slower or substantially zero RPM speed. In some embodiments, this mode may further include venting working fluid to manage working fluid pressures and/or maintain working fluid pressures within design and/or safe working limits.

In a tripped mode, active parasitic loads will be consistent with whatever mode preceded the Tripped mode, except where an active parasitic load also trips to a failsafe condition with a lower (or higher) load of the active parasitic loads. PHES system readiness exiting from tripped mode 1012 to another mode will vary depending on the initiating trip event.

B. PHES System Operating States and Transitional States Operating States

FIG. 11 is a state diagram illustrating operating states of a PHES system, including PHES system 1000, according to an example embodiment. FIG. 11 mirrors the primary modes of operation shown in FIG. 10 , including the preferred transitions between modes, as indicated by directional arrows between modes. FIG. 11 further adds additional detail regarding state conditions. Operating states are shown as headings in the blocks in FIG. 11 . Some of these states represent different versions of three common modes of operation (i.e., hot turning 1006, charge 1002, and generation 1004) and account for alternate configurations in which the non-primary powertrain may be operating in (e.g., slow rolling or not slow rolling). The PHES system operating states illustrated in FIG. 11 are “holding states” in which the PHES systems spend significant time.

CHARGE (GPT BASE) 1014 is a charge mode 1002 operating state where the GPT system (e.g., GPT system 200) is at a base level with low or no activity. Valves associated with GPT system operation are configured at a base level (e.g., for no rotation of the GPT system). The CPT system (e.g., CPT system 100) is in charge mode with CPT turbomachinery rotating at steady state (i.e., operating) speed. Valves associated with the CPT system are configured for steady state rotation of CPT turbomachinery, including connection to high-pressure working fluid paths. The hot-side loop is configured for HTS medium to flow from a warm HTS system (e.g., warm HTS system 591) to a hot HTS system (e.g., hot HTS system 592) via an HHX system (e.g., HHX system 500). The cold-side loop is configured for CTS medium to flow from a warm CTS system (e.g., warm CTS system 691) to a cold CTS system (e.g., cold CTS system 692) via a CHX system (e.g., CHX system 600). Ambient cooling of working fluid (e.g. AHX system 700) is bypassed.

GENERATION (CPT BASE) 1016 is a generation mode 1004 operating state where the CPT system (e.g., CPT system 100) is at a base level with low activity. Valves associated with CPT system operation are configured at a base level (e.g., for no rotation of the CPT system). The GPT system (e.g., GPT system 200) is in generation mode with GPT turbomachinery rotating at steady state (i.e., operating) speed. Valves associated with the GPT system are configured for steady-state rotation of GPT turbomachinery, including connection to high-pressure working fluid paths. The hot-side loop is configured for HTS medium to flow from the hot HTS system (e.g., hot HTS system 592) to the warm HTS system (e.g., warm HTS system 591). The cold-side loop is configured for CTS medium to flow from the cold CTS system (e.g., cold CTS system 692) to the warm CTS system (e.g., warm CTS system 691). Ambient cooling of working fluid (e.g. AHX system 700) is active with working fluid circulating through the AHX system 700.

CHARGE (GPT SLOW ROLLING) 1026 is a charge mode 1002 operating state where the GPT system (e.g., GPT system 200) is slow rolling (i.e., GPT turbomachinery is spinning at a minimum speed). Valves associated with GPT system operation are configured for recirculation of working fluid through the GPT system. The CPT system (e.g., CPT system 100) is in charge mode with CPT turbomachinery rotating at operating speed. Valves associated with the CPT system are configured for steady-state rotation of CPT turbomachinery, including connection to high-pressure working fluid paths. The hot-side loop is configured for HTS medium to flow from the warm HTS system (e.g., warm HTS system 591) to the hot HTS system (e.g., hot HTS system 592). The cold-side loop is configured for CTS medium to flow from the warm CTS system (e.g., warm CTS system 691) to the cold CTS system (e.g., cold CTS system 692). Ambient cooling of working fluid (e.g. AHX system 700) is bypassed.

GENERATION (CPT SLOW ROLLING) 1028 is a generation mode 1004 operating state where the CPT system (e.g., CPT system 100) is slow rolling (i.e., CPT turbomachinery is spinning at a minimum speed). Valves associated with CPT system operation are configured for recirculation of working fluid through the CPT system. The GPT system (e.g., GPT system 200) is in generation mode with GPT turbomachinery rotating at operating speed. Valves associated with the GPT system are configured for steady-state rotation of GPT turbomachinery, including connection to high-pressure working fluid paths. The hot-side loop is configured for HTS medium to flow from the hot HTS system (e.g., hot HTS system 592) to the warm HTS system (e.g., warm HTS system 591). The cold-side loop is configured for CTS medium to flow from the cold CTS system (e.g., cold CTS system 692) to the warm CTS system (e.g., warm CTS system 691). Ambient cooling of working fluid (e.g. AHX system 700) is active with working fluid circulating through the AHX system 700.

HOT TURNING (CPT SLOW ROLLING) 1018 is a hot turning mode 1008 operating state where CPT system (e.g., CPT system 100) is slow rolling (i.e., CPT turbomachinery is spinning at a minimum speed). Valves associated with CPT system operation are configured for recirculation of working fluid through the CPT system. GPT system (e.g., GPT system 200) is at a base level with low activity. Valves associated with GPT system operation are configured at a base level (e.g., for no rotation of the GPT system). Hot-side and cold-side loops are in standby, where the HTS and CTS media are resident in the associated heat exchangers and thermal media loop fluid paths (e.g., HHX system 500 and CHX system 600, respectively). Heat traces on the hot-side loop are turned on as necessary to keep HTS medium in liquid phase. The ambient heat exchanger system (e.g. AHX system 700) is set to active state. AHX valves are set to allow working fluid circulation through the AHX system, but no working fluid may actually be circulating through the AHX system due to recirculation and/or base state of the working fluid at the powertrain. With no working fluid circulation through the AHX system, AHX system fans are turned off.

HOT TURNING (GPT SLOW ROLLING) 1022 is a hot turning mode 1008 operating state where GPT system (e.g., GPT system 200) is slow rolling (i.e., GPT turbomachinery is spinning at a minimum speed). Valves associated with GPT system operation are configured for recirculation of working fluid through the GPT system. CPT system (e.g., CPT system 100) is at a base level with low activity. Valves associated with CPT system operation are configured at a base level (e.g., for no rotation of the CPT system). Hot-side and cold-side loops are in standby, where the HTS and CTS media are resident in the associated heat exchangers and thermal media loop fluid paths (e.g., HHX system 500 and CHX system 600, respectively). Heat traces on the hot-side loop are turned on as necessary to keep HTS medium in liquid phase. The ambient heat exchanger system (e.g. AHX system 700) is set to active state. AHX valves are set to allow working fluid circulation through the AHX system, but no working fluid may actually be circulating through the AHX system due to recirculation and/or base state of the working fluid at the powertrain. With no working fluid circulation through the AHX system, AHX system fans are turned off.

HOT TURNING (CPT+GPT SLOW ROLLING) 1020 is a hot turning mode 1008 operating state where GPT system (e.g., GPT system 200) is slow rolling (i.e., GPT turbomachinery is spinning at a minimum speed) and CPT system (e.g., CPT system 100) is slow rolling (i.e., CPT turbomachinery is spinning at a minimum speed). Valves associated with GPT system operation are configured for recirculation of working fluid through the GPT system. Valves associated with CPT system operation are configured for recirculation of working fluid through the CPT system. Hot-side and cold-side loops are in standby, where the HTS and CTS media are resident in the associated heat exchangers and thermal media loop fluid paths (e.g., HHX system 500 and CHX system 600, respectively). Heat traces on the hot-side loop are turned on as necessary to keep HTS medium in liquid phase. The ambient heat exchanger system (e.g. AHX system 700) is set to active state. AHX valves are set to allow working fluid circulation through the AHX system, but no working fluid may actually be circulating through the AHX system due to recirculation and/or base state of the working fluid at the powertrain. With no working fluid circulation through the AHX system, AHX system fans are turned off.

HOT STANDBY 1024 is a hot standby mode 1008 operating state. GPT system (e.g., GPT system 200) is at a base level with low activity. Valves associated with GPT system operation are configured at a base level (e.g., for no rotation of the GPT system). CPT system (e.g., CPT system 100) is at a base level with low activity. Valves associated with CPT system operation are configured at a base level (e.g., for no rotation of the CPT system). Hot-side and cold-side loops are in standby, where the HTS and CTS media are resident in the associated heat exchangers and thermal media loop fluid paths (e.g., HHX system 500 and CHX system 600, respectively). Heat traces on the hot-side loop are turned on as necessary to keep HTS medium in liquid phase. The ambient heat exchanger system (e.g. AHX system 700) is set to active state. AHX valves are set to allow working fluid circulation through the AHX system, but no working fluid may actually be circulating through the AHX system due to base state of the working fluid at the powertrain. With no working fluid circulation through the AHX system, AHX system fans are turned off.

COLD DRY STANDBY 1030 is a cold dry standby mode 1010 operating state. GPT system (e.g., GPT system 200) is off with no significant activity. Valves associated with GPT system operation are configured at a base level (e.g., for no rotation of the GPT system). CPT system (e.g., CPT system 100) is off with no significant activity. Valves associated with CPT system operation are configured at a base level (e.g., for no rotation of the CPT system). HTS and CTS media in hot-side and cold-side loops, respectively, are drained to HTS and CTS tanks, respectively (e.g., tank(s) 510 and/or 520; tank(s) 610 and/or 620). In one embodiment, HTS medium 590 in HHX 500 and associated fluid paths is drained to hot HTS tank 520, and HTS medium 590 in warm HTS tank 510 remains in warm HTS tank 510. In another embodiment, CTS medium 690 in CHX 600 and associated fluid paths is drained to warm CTS tank 610, and CTS medium 690 in cold CTS tank 620 remains in cold CTS tank 620. Additionally or alternatively, HTS medium 590 and CTS medium 690 may be pumped between their respective tanks in the same manner as a thermal media rebalancing operation. Hot-side and cold-side heat exchangers and associated thermal media loop fluid paths (e.g., HHX system 500 and CHX system 600, respectively) are empty of thermal storage media and HTS and CTS media are not actively circulating. One or more HTS system 501 heaters (e.g., heaters 512, 522) are active to maintain HTS medium resident in tanks (e.g., HTS tanks 510, 520) in liquid state.

Transitional States

In addition to the operating states (i.e., long-term holding states) shown in FIG. 11 , there are numerous additional transitionary states. These transitionary states would be within the paths shown by the arrows in FIG. 11 . Between operating states, there may be transitional states where one or more subsystems need to switch to their own respective states. The subsystems may change their state (e.g., valve actuation, pump speed change) in specific preferred sequences. These transitions and the intermediary transitionary states that make up the transitions are described in more detail below.

C. States of Generation Powertrain and Associated Valves

FIG. 12 and FIG. 13 are state diagrams illustrating select operating and transitional states of a PHES system, including PHES system 1000, each according to an example embodiment. These are example state transitions and other embodiments are possible as well. FIG. 12 and FIG. 13 are used primarily to illustrate generation powertrain state transitions. Other examples are provided herein reflecting other state transitions for other subsystems in a PHES system, for example, FIGS. 19, 20, 21, 22, and 23 and their associated descriptions.

FIG. 12 illustrates transition from the HOT STANDBY state 1024 to GENERATION (CPT BASE) state 1016, with intermediate transitional states 1034, 1036, 1038. During the transition from the HOT STANDBY state 1024 to GENERATION (CPT BASE) state 1016, the generation powertrain moves from the base state, at 1024 and 1034, to spin up to variable frequency drive state, at 1036, to power generation, at 1038 and 1016. The GPT valve system moves from its base state, at 1024, to bypassed state, at 1034 and 1036 and 1038, and then eventually to the connected state, at 1016. Beneficially, this overall transition process enables the generation powertrain to move through the spin up state with minimal load.

FIG. 13 illustrates transition from the GENERATION (CPT BASE) state 1016 to the HOT TURNING (GPT SLOW ROLLING) state 1022, with intermediate transitional states 1042 and 1044. During the transition from the GENERATION (CPT BASE) state 1016 to the HOT TURNING (GPT SLOW ROLLING) state 1022 (e.g., due to operator initiated shutdown of the generation mode 1004), the generation powertrain moves through the generation state, at 1016 and 1042, to the base state, at 1044, and then to the turning state, at 1022. The GPT valve systems move from a connected state, at 1016, to a bypass state, at 1042 and 1044, beneficially to allow the turbomachinery speed to drop, and eventually to a recirculation state, at 1022, beneficially to allow the rotor to cool down.

FIG. 14 further describes the generation powertrain (e.g., GPT system 200) states (i.e., GPT states) illustrated in FIGS. 12 and 13 . FIG. 14 is a state diagram illustrating generation powertrain states of a PHES system, including PHES system 1000, according to an example embodiment.

The states in FIG. 14 occur sequentially, for the most part, and correspond to startup and grid synchronization of the generation powertrain. The preferred sequential relationship of these states, with expected allowable transitions, is indicated by directional arrows between states.

At GPT Base state 1048, the generation powertrain is not driven. It is typically not spinning (i.e., at zero RPM), but it may still be spinning as it comes into this state from another state in which it was spinning Both generation circuit breakers (e.g., 211, 212) are open. The generation powertrain is ready to be spun.

At GPT Spin Up state 1050, the generation powertrain is connected to, and driven by, the VFD, spinning up to rated speed. For grid connections, once at grid speed, the generator (e.g., generation system 230) may not yet be synchronized to the external electrical grid.

GPT Generation state 1052, is a typical operating state for the generation mode 1004. At this state, the generation powertrain is spinning at rated speed (i.e., steady state) and the circuit breaker to the grid is closed. The generation powertrain is connected to the grid.

GPT Slow Roll state 1054, is a typical state for the generation powertrain when the PHES system is in charge mode 1002, unless the GPT system has cooled to the point that it can be in the base state. At this state, the generation powertrain is spinning at a low speed (i.e., slow rolling). A generation turning motor (e.g., 221-1) is on to maintain the slow rotational speed of the generation powertrain.

The generation powertrain states illustrated in FIGS. 12, 13, and 14 can be further described with respect to the electrical status of the power interface 2002. Table I lists power interface 2002 component status for GPT states illustrated in FIGS. 12, 13, and 14 .

TABLE 1 Status GPT GPT GPT GPT Base Spin Up Generation Slow Roll 1048 1050 1052 1054 VFD 214 Off On Off Off VFD-to-GEN Open Closed Open Open Breaker 211 GEN grid-connect Open Open Closed Open Breaker 212 GEN Turning Motor Off Off Off On 221-1

Transitions between generation powertrain states are described in the following paragraphs, with steps recited in preferred sequence. Component references refer to example embodiment GPT system 200, but the steps may be applied to other configurations to accomplish the same state transitions.

GPT Base 1048 to GPT Spin Up 1050. For this state transition, the working fluid loop valving configuration and pressure must be at the right state before this transition can take place, as described below with respect to GPTV states. Power is first applied to a motor to spin the generation powertrain. In GPT system 200, VFD-to-generator breaker 211 is closed and VFD 214 is turned on, resulting in the generation powertrain spinning. Generator 210-1 is acting as a motor and accepting current from VFD 214. Compressor 230-1 and turbine 240-1 are spinning. The motor speed is then increased via VFD 214, bringing the generation powertrain up to a grid-synchronous speed.

GPT Spin Up 1050 to GPT Generation 1052. This transition is a grid-synchronization transition. Motor (e.g., generator 210-1 acting as a motor) speed is adjusted through current control (e.g., at VFD 214) to ensure grid-synchronous speed and to prevent speed overshoot. Motor phase is adjusted (e.g., at VFD 214) until the motor phase is grid synchronous. Power supply from grid to motor is shutoff (e.g., grid-connect breaker 212 is closed), and the motor then acts as a generator to supply power to the grid (e.g., VFD-to-generator breaker 211 is opened). The VFD will then start powering down to zero.

GPT Generation 1052 to GPT Base 1048. This transition can happen, for example, during both normal shutdown of the generation powertrain and during a trip event. Power supply from grid to motor is opened (e.g., grid-connect breaker 212 is opened). Once the generation powertrain has transitioned into GPT Base 1048 (after opening of the breaker), the generation powertrain will still be spinning, and will start ramping down to zero speed unless the powertrain is further transitioned to the GPT Slow Rolling 1054 state prior to spinning down to zero.

GPT Spin Up 1050 to GPT Base 1048. This transition could happen, for example, due to a trip signal. The VFD (e.g., VFD 214) is turned off and no longer connected to the generator (e.g., VFD-to-generator breaker 211 is opened). Once the generation powertrain has transitioned into GPT Base 1048 (after opening of the breaker), the generation powertrain will still be spinning, and will start ramping down to zero speed unless the generation powertrain is further transitioned to the GPT Slow Rolling 1054 state prior to spinning down to zero

GPT Base 1048 to GPT Slow Rolling 1054. This transition takes place by turning on the turning motor (e.g., turning motor 221-1), which turns the drive train (e.g., generation turbomachinery 230-1, 240-1) at a very low, “slow rolling speed” (e.g., 0.1% to 1%, 1% to 5%, or 5% to 10% of steady state generation RPM). In normal operation, as the drive train ramps down in speed, the turning motor will be turned on during ramp down to ensure the speed of the turbomachinery drivetrain does not slow down below the slow rolling speed, or if the speed slows below the slow rolling speed, then it is brought back to the slow rolling speed. This can be accomplished through an overrunning clutch (e.g., overrunning clutch 221-2) connected between the turning motor and the drivetrain that disengages when the driver side (e.g. drivetrain) of the clutch is operating at speeds higher than the slow rolling speed, and engages when the driver side of the clutch is operating at speeds lower than or equal to the slow rolling speed. This results in the turning motor engaging with the turbine when the turbine reaches the speed of the turning motor. The motor will then maintain the slow rolling speed.

GPT Slow Rolling 1054 to GPT Base 1048. The turning motor (e.g., turning motor 221-1) is turned off. The generation powertrain will subsequently coast down to substantially zero rpm.

GPT Slow Rolling 1054 to GPT Spin Up 1050. To start the generation startup process with the generation powertrain spinning, the powertrain can transition directly from GPT Slow Rolling 1054 to GPT Spin Up 1050 by sequentially connecting the VFD to the generator (acting as a motor) (e.g., closing VFD-to-generator breaker 211) and turning off the turning motor (e.g., turning motor 221-1).

The generation powertrain transitional states illustrated in FIGS. 12 and 13 can also be further described with respect to the valve states associated with generation powertrain, including, for example, bypass and recirculation loops.

FIG. 16 is a state diagram illustrating generation powertrain (e.g., GPT system 200) valve states (i.e., GPTV states), of a PHES system, including PHES system 1000, from a generation powertrain perspective (e.g., GPT system 200 and associated GPT system 200 bypass/recirculation valves), according to an example embodiment.

The states in FIG. 16 occur sequentially, for the most part. The preferred sequential relationship of these states, with expected allowable transitions, is indicated by directional arrows between states.

At GPTV Base state 1064, the valves are configured to have both recirculation valves and the bypass valves open. This is considered a fail-safe state.

At GPTV Recirculation state 1070, the generation working fluid valves are configured such that they can provide working fluid circulation and any desired heat removal for the generation powertrain (e.g., GPT system 200) as it spins at a low rate (e.g., slow rolling speed). The generation powertrain is also isolated from the high-pressure side of the working fluid loop (e.g., working fluid loop 300).

At GPTV Bypassed state 1066, the bypass valve is open in addition to the isolation (shutoff) valves. This allows working fluid to bypass the generation turbine partially, which allows the control of the turbine power generation prior to reaching full speed and closing the breaker. Beneficially, this allows the use of a uni-directional VFD (e.g., VFD 214).

At GPTV HP Connected state 1068, the generation working fluid valves are configured such that working fluid can be circulated between the high-pressure side and the low-pressure side via the generation powertrain. All the working fluid bypass loops are closed to prevent loss. Valve 229 is closed but may be in a state where it is ready to be opened quickly to help with anti-surge as necessary in case of a trip event.

Table II lists valve status for state transitions illustrated in FIGS. 12 and 13 and GPTV states illustrated in FIG. 16 .

TABLE II Status GPTV GPTV GPTV GPTV Base Recirculation Bypassed HP Connected 1064 1070 1066 1068 Compressor Shutoff Closed Closed Open Open Valve 231 (fails closed) Turbine Shutoff Closed Closed Open Open Valve 241 (fails closed) Compressor Bypass Open Closed Open Closed Valve 229 (fails open) Compressor Recirc Open Open Closed Closed Valve 232 (fails closed) Turbine Recirc Open Open Closed Closed Valve 242 (fails open) Bypass Path Closed Closed Closed Closed Valve 222 (fails open) Bypass Path Closed Closed Closed Closed Valve 401

Further illustrating the GPTV states, FIGS. 3A, 3B, 3C, and 3D each illustrate a portion of FIG. 3 encompassing GPT system 200 and associated bypass/recirculation valves, each according to an example embodiment. FIG. 3A illustrates GPTV base state 1064. FIG. 3B illustrates GPTV Bypass state 1066. FIG. 3C illustrates GPTV Recirculation state 1070. FIG. 3D illustrates GPTV HP Connected state 1068. Valve positions are indicated in FIGS. 3A, 3B, 3C, and 3D with a filled valve icon representing a closed valve and an unfilled valve icon representing an open valve. For example, in FIG. 3A, valve 231 is closed and valve 232 is open.

Transitions between generation powertrain valve (GPTV) states are described in the following paragraphs, with steps recited in preferred sequence. Component references refer to example embodiments GPT system 200 and working fluid loop 300, but the steps may be applied to other configurations to accomplish the same GPTV state transitions.

GPTV Base 1064 to GPTV Recirculation 1070. Turbine bypass fluid path is closed (e.g., valve 229 is closed).

GPTV Base 1064 to GPTV Bypassed 1066. Compressor recirculation fluid path and turbine recirculation fluid path are closed (e.g., valve 232 and valve 242 are closed). Turbine bypass fluid path (e.g., valve 229) remains open to allow working fluid to go through the bypass loop. Compressor outlet (shutoff) valve 231 is opened. Turbine inlet (shutoff) valve 241 is opened.

GPTV Bypassed 1066 to GPTV HP Connected 1068. Turbine bypass fluid path is closed (e.g., valve 229 is closed).

GPTV Bypassed 1066 to GPTV Base 1064. Generation powertrain recirculation fluid paths are opened (e.g., recirculation valves 232, 242 are opened). Turbine inlet fluid paths are closed (e.g., valve 241 is closed). Compressor outlet fluid path is closed (e.g., valve 231 is closed).

GPTV HP Connected 1068 to GPTV Base 1064. This transition can happen, for example, due to a trip event. Turbine inlet fluid paths are quickly closed (e.g., valve 241 is quickly closed). Turbine bypass fluid path is quickly opened (e.g., valve 229 is quickly opened) to help with anti-surge. Compressor outlet fluid path is closed (e.g., valve 231 is closed). Generation powertrain recirculation fluid paths are opened (e.g., recirculation valves 232, 242 are opened).

GPTV HP Connected 1068 to GPTV Bypassed 1066. This transition generally happens during normal shut down. Turbine bypass fluid path is opened (e.g., valve 229 is opened) to help with anti-surge.

GPTV Recirculation 1070 to GPTV Base 1064. Turbine bypass fluid path is opened (e.g., valve 229 is opened).

D. States of Charge Powertrain and Associated Valves

FIG. 15 is a state diagram illustrating charge powertrain (e.g., CPT system 100) states (i.e., CPT states) of a PHES system, including PHES system 1000, according to an example embodiment.

The states in FIG. 15 occur sequentially, for the most part. The preferred sequential relationship of these states, with expected allowable transitions, is indicated by directional arrows between states.

At CPT Base state 1056, the charge powertrain is not driven. It is typically not spinning (i.e., at zero RPM), but it may still be spinning as it comes into this state from another state in which it was spinning Both charge circuit breakers (e.g., 111, 112) are open. The charge powertrain is ready to be spun.

At CPT Spin Up state 1058, the charge powertrain is connected to, and driven by, the VFD, spinning up to rated speed. For grid connections, once at grid speed, the motor (e.g., charge motor system 110) is not yet synchronized to the external electrical grid.

CPT Charge state 1060, is a typical operating state for the charge mode 1002. At this state, the charge powertrain is spinning at rated speed (i.e., steady state) and the circuit breaker to the grid is closed. The charge powertrain is connected to the grid.

CPT Slow Rolling state 1062, is a typical state for the charge powertrain when the PHES system is in generation mode 1004, unless the CPT system has cooled to the point that it can be in the base state. At this state, the charge powertrain is spinning at a very low, “slow rolling speed” (e.g., 0.1% to 1%, 1% to 5%, or 5% to 10% of steady state charge RPM). A charge turning motor (e.g., 121-1) is on to maintain the slow rolling speed of the charge powertrain.

The charge powertrain states illustrated in FIG. 15 can be further described with reference to the electrical status of the power interface 2002, illustrated in FIG. 9 , which can control electrical power in the CPT system 100. Table III lists power interface 2002 component status, and charge turning motor, for CPT states illustrated in FIG. 15 .

TABLE III Status CPT CPT CPT CPT Base Spin Up Charge Slow Roll VFD 214 Off On Off Off VFD-to-CHG-Motor Open Closed Open Open Breaker 111 CHG Motor Grid-connect Open Open Closed Open Breaker 112 CHG Turning Motor Off Off Off On 121-1

Transitions between charge powertrain states are described in the following paragraphs, with steps recited in preferred sequence. Component references refer to example embodiment CPT system 100 and power interface 2002, but the steps may be applied to other configurations to accomplish the same state transitions.

CPT Base 1056 to CPT Spin Up 1058. For this state transition, the working fluid loop valving configuration and pressure must be at the right state before this transition can take place, as described below with respect to CPTV states. Power is first applied to a motor (e.g., motor 110-1) to spin the charge powertrain. For CPT system 100, VFD-to-motor breaker 111 is closed and VFD 214 is turned on, resulting in the charge powertrain spinning Compressor system 1301 and turbine system 140 are spinning. The motor speed is then increased via VFD 214, bringing the generation powertrain up to a grid-synchronous speed.

CPT Spin Up 1058 to CPT Charge 1060. This transition is a grid-synchronization transition. Motor (e.g., motor 110-1) speed is adjusted through current control (e.g., at VFD 214) to ensure grid-synchronous speed and to prevent speed overshoot. Motor phase is adjusted (e.g., at VFD 214) until the motor phase is grid synchronous. Power supply from grid to motor is activated (e.g., grid-connect breaker 112 is closed), and VFD power to motor is stopped (e.g., VFD-to-motor breaker 111 is opened). The VFD will then start powering down to zero.

CPT Charge 1060 to CPT Base 1056. This transition happens, for example, during both normal shutdown of the charge powertrain and during a trip event. Power supply from grid to motor is halted (e.g., grid-connect breaker 112 is opened). Once the charge powertrain has transitioned into CPT Base 1056 (upon the opening of the breaker), the charge powertrain will still be spinning, and will start ramping down to zero speed unless the powertrain is further transitioned to the CPT Slow Rolling 1062 state prior to spinning down to zero.

CPT Spin Up 1058 to CPT Base 1056. This transition could happen, for example, due to a trip signal. The VFD (e.g., VFD 214) is turned off and no longer connected to the motor (e.g., VFD-to-motor breaker 111 is opened). Once the charge powertrain has transitioned into CPT Base 1056 (upon the opening of the breaker), the charge powertrain will still be spinning, and will start ramping down to zero speed unless the charge powertrain is further transitioned to the CPT Slow Rolling 1062 state prior to spinning down to zero

CPT Base 1056 to CPT Slow Rolling 1062. This transition takes place by turning on the turning motor (e.g., turning motor 121-1), which turns the drivetrain (e.g., charge turbomachinery 130-1, 140-1) at a low speed (e.g., slow rolling speed). In normal operation, as the drivetrain ramps down in speed, the turning motor will be turned on during ramp down to ensure the speed of the drivetrain does not slow down below the minimum speed, or if the speed slows below the minimum speed, then it is brought back to the minimum speed. This can be accomplished through an overrunning clutch (e.g., overrunning clutch 121-2) connected between the turning motor and the drivetrain that disengages when the driver side (e.g., drivetrain) of the clutch is operating at speeds higher than a minimum speed (e.g., slow rolling speed), and engages when the driver side of the clutch is operating at speeds lower than or equal to a minimum speed (e.g., slow rolling speed). This results in the turning motor engaging with the turbine when the turbine reaches the speed of the turning motor. The motor will then maintain the low (e.g., slow rolling) speed.

CPT Slow Rolling 1062 to CPT Base 1056. The turning motor (e.g., turning motor 121-1) is turned off. The charge powertrain will subsequently coast down to zero rpm.

CPT Slow Rolling 1062 to CPT Spin Up 1058. To start the charge startup process with the charge powertrain spinning, the powertrain can transition directly from CPT Slow Rolling 1062 to CPT Spin Up 1058 by sequentially connecting the VFD to the motor (e.g., closing VFD-to-motor breaker 111) and turning off the turning motor (e.g., turning motor 121-1).

Charge powertrain transitional states can also be further described with respect to the valve states associated with charge powertrain bypass and recirculation loops.

FIG. 17 is a state diagram illustrating charge powertrain (e.g., CPT system 100) valve states (i.e., CPTV states), of a PHES system, including PHES system 1000, from a charge powertrain perspective (e.g., CPT system 100 and associated CPT system 100 bypass/recirculation valves), according to an example embodiment.

The states in FIG. 17 occur sequentially, for the most part. The preferred sequential relationship of these states, with expected allowable transitions, is indicated by directional arrows between states.

At CPTV Base state 1072, the valves are configured to have both recirculation valves and the bypass valves open. This is considered a fail-safe state.

At CPTV Recirculation state 1078, the generation working fluid valves are configured such that they can provide working fluid circulation and any desired heat removal for the charge powertrain (e.g., CPT system 100) as it spins at a slow rate (e.g., slow rolling speed). The charge powertrain is also isolated from the high-pressure side of the working fluid loop.

At CPTV Bypassed state 1074, the bypass valve is open in addition to the isolation valves. This allows working fluid to circulate via a bypass loop to reduce load on the charge compressor (e.g., compressor system 130).

At CPTV HP Connected state 1076, the charge working fluid valves are configured such that working fluid can be circulated between the high-pressure side and the low-pressure side via the charge powertrain. All the working fluid bypass loops are closed to prevent loss. Valve 119 is closed but in a state where it is ready to be opened quickly to help with anti-surge as necessary in case of a trip event.

Table IV lists valve status for CPTV states illustrated in FIG. 17 .

TABLE IV Status CPTV CPTV CPTV CPTV HP Base Recirculation Bypassed Connected Valve 1072 1078 1074 1076 Compressor Shutoff Closed Closed Open Open Valve 131 (fails closed) Turbine Shutoff Closed Closed Open Open Valve 141 (fails closed) Compressor Bypass Open Closed Open Closed Valve 119 (fails closed) Compressor Recirc Open Open Closed Closed Valve 132 (fails closed) Turbine Recirc Open Open Closed Closed Valve 142 (fails open)

Further illustrating the CPTV states, FIGS. 3E, 3F, 3G, and 3H each illustrate a portion of FIG. 3 encompassing CPT system 100 and associated bypass/recirculation valves, each according to an example embodiment. FIG. 3E illustrates CPTV base state 1072. FIG. 3F illustrates CPTV Bypass state 1074. FIG. 3G illustrates CPTV Recirculation state 1078. FIG. 3H illustrates CPTV HP Connected state 1076. Valve positions are indicated in FIGS. 3E, 3F, 3G, and 3H with a filled valve icon representing a closed valve and an unfilled valve icon representing an open valve. For example, in FIG. 3E, valve 131 is closed and valve 132 is open.

Transitions between charge powertrain valve (CPTV) states are described in the following paragraphs, with steps recited in preferred sequence. Component references refer to example embodiments CPT system 100 and working fluid loop 300, but the steps may be applied to other configurations to accomplish the same CPTV state transitions.

CPTV Base 1072 to CPTV Recirculation 1078. Compressor high-flow recirculation fluid path is closed (e.g., valve 119 is closed).

CPTV Base 1072 to CPTV Bypassed 1074. Compressor recirculation fluid path and turbine recirculation fluid path are closed (e.g., valve 132 and valve 142 are closed). Compressor high-flow recirculation fluid path (e.g., valve 119) remains open to allow working fluid to go through the recirculation loop. Compressor outlet valve 131 is opened. Turbine inlet valve 141 is opened.

CPTV Bypassed 1074 to CPTV HP Connected 1076. Compressor high-flow recirculation fluid path is closed (e.g., valve 119 is closed).

CPTV Bypassed 1074 to CPTV Base 1072. Charge powertrain recirculation fluid paths are opened (e.g., recirculation valves 132, 142 are opened). Turbine inlet fluid path is closed (e.g., valve 141 is closed). Compressor outlet fluid path is closed (e.g., valve 131 is closed).

CPTV HP Connected 1076 to CPTV Base 1072. This transition may happen, for example, due to a trip event. Turbine inlet fluid path is quickly closed (e.g., valve 141 is quickly closed). Compressor high-flow recirculation fluid path is quickly opened (e.g., valve 119 is quickly opened) to help with anti-surge. Compressor outlet fluid path is closed (e.g., valve 131 is closed). Charge powertrain recirculation fluid paths are opened (e.g., recirculation valves 132, 142 are opened).

CPTV HP Connected 1076 to CPTV Bypassed 1074. This transition can happen, for example, during normal shut down or during a grid trip event. Compressor high-flow recirculation fluid path is opened (e.g., valve 119 is opened) to help manage the pressure ratio across the compressor and avoid compressor surge.

CPTV Recirculation 1078 to CPTV Base 1072. Compressor high-flow recirculation fluid path is opened (e.g., valve 119 is opened).

E. States of Ambient Heat Exchanger and Associated Valves

FIG. 18 is a state diagram illustrating ambient cooler (also referred to as ambient heat exchanger) states (e.g., AHX system 700) of a PHES system, including PHES system 1000, according to an example embodiment. The two states in FIG. 18 can transition back-and-forth, as indicated by directional arrows between the states.

Example ambient cooler states include, Ambient Cooler Bypassed 1080, Ambient Cooler Active 1082, and Ambient Cooler Off 1084. During Ambient Cooler Off 1084, working fluid loop valves regulating working fluid flow paths into or out of the ambient cooler (e.g., AHX system 700) are all closed, preventing movement of working fluid into or out of the ambient cooler. Ambient cooler fans, if present, are off. During Ambient Cooler Bypassed 1080, working fluid loop valves are configured such that the ambient cooler is bypassed by working fluid circulating in the working fluid loop (e.g. working fluid loop 300). Ambient cooler fans, if present, are off. During Ambient Cooler Active 1082, working fluid loop valves are configured such that working fluid in the working fluid loop can enter the ambient cooler. If the working fluid is actually circulating through the ambient cooler, the ambient cooler removes heat from working fluid in the working fluid loop and exhausts it the environment; this state may, for example, be used during generation mode 1004 and the bypass state 1080 may, for example, be used during charge mode 1002. Ambient cooler fans, if present, may be used to vary the rate of heat extraction from the working fluid. Ambient cooler fans may be turned on, and may have their speed adjusted, when working fluid is actively circulating through the ambient cooler, and the fans may be turned off if the working fluid is not actively circulating through the ambient cooler, regardless of valve configuration.

Alternatively, in other embodiments of PHES systems and/or working fluid loop, an ambient cooler (e.g., AHX system 700) can be configured to be continuously connected to the working fluid loop (i.e., no bypass state is available). In these alternative embodiments, the fans or other equipment (e.g., heat sink fluid flow rate) are used to vary the heat removal capability of the ambient cooler. For example, during generation mode 1004, ambient cooler fans are turned on to actively remove heat from the working fluid, and during generation mode 1002, when ambient cooler fans are turned off, the ambient cooler does not passively remove a significant amount of heat from the working fluid.

Table V lists cooler and valve status for ambient cooler (e.g., AHX system 700) states illustrated in FIG. 18 .

TABLE V Status Ambient Cooler Ambient Cooler Ambient Cooler Bypassed Active Off 1080 1082 1084 Bypass Open Closed Closed Valve 323 Cold-side Isolation Closed Open Closed Valve 324 Recuperator-side Closed Open Closed Isolation Valve 325 AHX Fans Fan Off Fan On Fan Off

Further illustrating ambient cooler states 1080 and 1082, FIGS. 3I and 3J each illustrate a portion of FIG. 3 encompassing AHX system 700 and associated bypass valves, according to an example embodiment. FIG. 3I illustrates ambient cooler bypass state 1080. FIG. 3J illustrates ambient cooler active state 1082. Valve positions are indicated in FIGS. 3I and 3J with a filled valve icon representing a closed valve and an unfilled valve icon representing an open valve. For example, in FIG. 3I, valve 324 is closed and valve 323 is open.

In an alternative valve arrangement for the ambient cooler states 1080 and 1082, FIGS. 3K and 3L each illustrate a portion of FIG. 3 , but with valve 325 removed. FIG. 3K illustrates ambient cooler bypass state 1080. FIG. 3L illustrates ambient cooler active state 1082. Valve positions are indicated in FIGS. 3K and 3L with a filled valve icon representing a closed valve and an unfilled valve icon representing an open valve. For example, in FIG. 3K, valve 324 is closed and valve 323 is open. The valve states in Table V are applicable to both FIGS. 3I, 3J and FIGS. 3K, 3L, with the exception that valve 325 states are not applicable to FIGS. 3K, 3L.

Transitions between ambient cooler states are described in the following paragraphs, with steps recited in preferred sequence. Component references refer to example embodiments of AHX system 700 and working fluid loop 300, but the steps may be applied to other configurations to accomplish the same ambient cooler state transitions.

Ambient Cooler Bypassed 1080 to Ambient Cooler Active 1082. This transition may occur, for example, for mode switch from charge mode 1002 to generation mode 1004 or from start up (e.g., cold dry standby mode 1010) to hot standby 1024. Isolation valves 324 and 325 (if present) are opened. Bypass valve 323 is closed. If working fluid is circulating through the ambient cooler (e.g. AHX system 700), fans (e.g., fans in AHX system 700) are turned on and fan speed may be controlled for desired heat removal.

Ambient Cooler Active 1082 to Ambient Cooler Bypassed 1080. This transition may occur, for example, for mode switch from generation mode 1004 to charge mode 1002. Isolation valves 324 and 325 (if present) are closed. Bypass valve 323 is opened. Fans (e.g., fans in AHX system 700) are turned off.

Ambient Cooler Active 1082 to Ambient Cooler Off 1084. This transition may occur, for example, for mode switch from hot standby 1008 and/or 1024 to cold dry standby 1010 and/or 1030. Isolation valves 324 and 325 (if present) are closed. Bypass valve 323 is closed. Fans (e.g., fans in AHX system 700) are turned off.

F. States and Control of Inventory Control System

The working fluid inventory control system (ICS) is part of the working fluid loop subsystem (e.g., working fluid loop 300). The inventory control system may include a compressor, a filtering system to condition the working fluid, one or more working fluid tanks, fluid paths, and valves to manage the various requirements from this system.

Example components of an ICS 390 embodiment, as implemented in working fluid loop 300, are shown in FIG. 3M. FIG. 3M illustrates a portion of FIG. 3 encompassing an inventory control system, according to an example embodiment.

As illustrated in FIG. 24 , one or more control systems may be used to control ICS system 390. A PHES supervisory controller 1124 may determine and/or direct PHES system 1000 modes and/or states, which may include ICS system 390 modes and/or states. Alternatively or additionally, an ICS controller 1125 may receive directives from PHES supervisory controller 1124, responsively enact changes in ICS 390, and report conditions to PHES supervisory controller 1124. For example, a power demand signal can be sent from PHES supervisory controller 1124 to ICS controller 1125. The ICS controller 1125 may then determine valve sequences and operations based, for example, on current PHES system conditions and the power demand signal. Alternatively or additionally, PHES supervisory controller 1124 may enact changes in ICS 390. For example, PHES supervisory controller 1124 may determine a new power demand level in the PHES system 1000 and responsively direct valve sequences and operations based, for example, on current PHES system conditions and power requirements, to reach that power demand level.

During normal operation, in order to increase power in the PHES system 1000, a controller (e.g., controller 1125 and/or controller 1124) can increase the working fluid pressure. To accomplish this, the controller can cause the following:

-   -   Open valve 312 to throttle working fluid from low-pressure tank         system 310 into the low-pressure side of the working fluid loop         300. This increases the inlet pressure into the CPT system 100         or GPT system 200, which will, in turn, increase the power of         the PHES system 1000.     -   Determine current PHES system 1000 power level and compare to         the power demand level. This step may be repeated until: (i) the         current power level matches the demand level, or (ii) there is         no more driving head (the pressure in low-pressure tank system         310 is only marginally above the working fluid loop 300 low-side         pressure). The latter stop condition can be determined, for         example, by comparing low-pressure tank system 310 pressure and         working fluid loop 300 low-side pressure, or by determining that         current power levels have ceased increasing. If either of these         stop conditions are met, close valve 312.     -   Determine if further power increase is still required (i.e., the         second stop condition above occurred prior to reaching demand         level). If further power increase is required, open valve 322 to         add working fluid from the high-pressure tank system 320 into         the low-pressure side of the working fluid loop 300. This can be         continued until the PHES system 1000 reaches the demand power         level. The ICS tank systems 310, 320 are preferably sized such         that the PHES system 1000 can get to full power in either charge         mode 1002 or generation mode 1004.

To decrease the power in the PHES system 1000, a controller (e.g., controller 1125 and/or controller 1124) can decrease the working fluid pressure. To accomplish this, the controller can cause the following:

-   -   Open valve 321 to throttle working fluid from the high-pressure         side of the working fluid loop 300 into high-pressure tank         system 320. This decreases the inlet pressure into the CPT         system 100 or GPT system 200, which will, in turn, decrease the         power of the PHES system 1000.     -   Determine current PHES system 1000 power level and compare to         the power demand level. This step may be repeated until: (i) the         current power level matches the demand level, or (ii) there is         no more driving head (high-pressure side of the working fluid         loop 300 is only marginally above the pressure in high-pressure         tank system 320). The latter stop condition can be determined,         for example, by comparing high-pressure tank system 320 pressure         and working fluid loop 300 high-side pressure, or by determining         that current power levels have ceased decreasing. If either of         these stop conditions are met, close valve 321.     -   Determine if further power decrease is still required (i.e., the         second stop condition above occurred prior to reaching demand         level). If further power decrease is required, open valve 311 to         add working fluid from the high-pressure side of the working         fluid loop 300 into the low-pressure tank system 310. This can         be continued until the PHES system 1000 reaches the demand power         level. The ICS tank systems 310, 320 are preferably sized such         that the system can get to minimum power in either charge mode         1002 or generation mode 1004.

Other functions ICS controller 1125 can perform include bringing the working fluid loop 300 pressures to a desired pressure (e.g., base, ambient, P_(standby), specific pressure range(s) that are below either or both the current pressures in the working fluid high-side fluid paths and low-side fluid paths) following a normal shutdown or a trip event so that the PHES system can be restarted.

Following a trip event, a controller (e.g., controller 1125 and/or controller 1124) can cause the following:

-   -   Open valve 318 to bleed working fluid from high-pressure working         fluid paths into low-pressure tank system 310. By using large         valve 318 (instead of or in addition to valve 311), this can         reduce the pressure in the high-pressure working fluid paths at         a rate fast enough to help maintain a settle-out pressure below         a threshold limit.     -   Close valve 318 once pressure in low-pressure tank system 310 is         substantially equal to that of the high-pressure working fluid         paths.     -   Open valve 305 and then turn on compressor 303 to draw working         fluid from high-pressure working fluid paths into high-pressure         tank system 320 until the high-pressure working fluid paths are         within a desired high-pressure range.     -   Turn off compressor 303 and then close valve 305.     -   Open valve 304 and then turn on compressor 303 to draw working         fluid from low-pressure working fluid paths into the         high-pressure tank system 320 until the low-pressure working         fluid paths are within a desired low-pressure range.

If the PHES system 1000 is shut down normally, large valve 318 may not need to be opened because the pressure in the high-pressure working fluid paths has been slowly reduced during the process to substantially a base level. Accordingly, a controller (e.g., controller 1125 and/or controller 1124) can cause the following:

-   -   Open valve 305 and then turn on compressor 303 to draw working         fluid from high-pressure working fluid paths into high-pressure         tank system 320 until the pressure in high-pressure working         fluid paths are at a base pressure.     -   Turn off compressor 303 and then close valve 305.     -   Open valve 304 and then turn on compressor 303 to draw working         fluid from low-pressure working fluid paths into the         high-pressure tank system 320 until the low-pressure working         fluid paths are at a base pressure. This should take only a         short time because the low-pressure working fluid paths should         already be very close to base pressure.

If the working fluid loop 300 leaks working fluid, to controller (e.g., controller 1125 and/or controller 1124) can cause additional working fluid to be added to the working fluid loop 300 as follows. Steps are described as if from a state where all referenced valves are initially closed:

-   -   Open valve 302.     -   Turn on compressor 303 to add working fluid from ambient air         when air is the working fluid or from an external working fluid         make-up reservoir (not shown) into high-pressure tank system 320         until high-pressure tank system 320 reaches a desired pressure.     -   Turn off compressor 303.     -   Close valve 302.     -   Open valve 322 to add working fluid from high-pressure tank         system 320 to low-pressure working fluid paths.     -   Close valve 322.     -   Repeat above steps until the working fluid loop pressure is at a         desired level.

G. States of Hot-Side Loop

FIG. 25 is a state diagram illustrating hot-side loop (also referred to as HTS loop) states of a PHES system, including PHES system 1000, according to an example embodiment. The hot-side loop is the flow path of circulating HTS medium 590, for example, through HTS system 501 in FIG. 4 and, in some states, HHX system 500 in FIGS. 2, 3, 6A, and 6B.

The states in FIG. 25 occur sequentially, for the most part. The preferred sequential relationships of these states are indicated by directional arrows between states.

At Drained state 1146, HTS medium 590 in fluid paths, including heat exchangers, has been drained or is being drained into the HTS tanks (e.g., 510 and/or 520). Heat trace 560 is off. When coming out of drained state 1146, e.g., to standby state 1138, heat trace 560 may be turned on prior to reintroduction of HTS medium 590 into fluid paths.

At Standby state 1138, the hot-side loop is filled or filling with HTS medium 590 and is ready for HTS medium 590 to flow. If the loop is not already filled, then a small flow rate would be temporarily established in the appropriate direction in order to fill the fluid paths with HTS medium 590.

At Flow-to-Hot state 1140, the hot-side loop is configured to allow HTS medium 590 flow from warm HTS system 591 to hot HTS system 592 (e.g., from warm HTS tank 510 to hot HTS tank 520 in HTS system 501) via the hot-side heat exchanger(s) (e.g., HHX system 500). Warm pump 530 is on to deliver this flow. Heat trace 560 may be turned off because HTS medium 590 is already hot. Bypass valve 551 is closed so that HTS medium 590 flows through HHX system 500.

At Flow-to-Warm state 1142, the hot-side loop is configured to allow HTS medium 590 flow from hot HTS system 592 to warm HTS system 591 (e.g., from hot HTS tank 520 to warm HTS tank 510 in HTS system 501) via the hot-side heat exchanger(s) (e.g., HHX system 500). Hot pump 540 is on to deliver this flow. Heat trace 560 may be turned off because HTS medium 590 is already hot. Bypass valve 551 is closed so that HTS medium 590 flows through HHX system 500.

At Bypassed state 1144, HTS medium 590 is flowing in the hot-side loop preferably from hot HTS system 592 to warm HTS system 591 (e.g., from hot HTS tank 520 to warm HTS tank 510 in HTS system 501), but not through the hot-side heat exchanger(s) (e.g., HHX system 500). Hot-side heat exchanger(s) are bypassed by opening bypass valve 551 and closing isolation valves 555, 556. Alternatively, in another embodiment, HTS medium 590 could flow in the hot-side loop from warm HTS system 591 to hot HTS system 592 (e.g., from warm HTS tank 510 to hot HTS tank 520 in HTS system 501), but not through the hot-side heat exchanger(s) (e.g., HHX system 500).

Table VI lists equipment status for hot-side loop states illustrated in FIG. 25 . Component references refer to example embodiments illustrated in, for example, FIGS. 2, 3, 4, 6A, and 6B, and including HTS system 501 and HHX system 500, but the status may be applied to other configurations to accomplish the same hot-side loop state states.

TABLE VI Status Drained Standby Flow-to-Hot Flow-to-Warm Bypassed 1146 1138 1140 1142 1144 HX Bypass Closed Closed Closed Closed Open Valve 551 Heat Trace 560 Off On Off Off Off Warm Pump 530 Off Off On Off *2 Warm Heater 512 *1 On On On On Warm Inflow Closed Closed Closed Open *3 Valve 511 Warm Pump Outlet Closed Open Open Closed *2 Valve 557 HX Warm Isolation Closed Open Open Open Closed Valve 555 Warm Drain Open Closed Closed Closed Closed Valve 552 Hot Pump 540 Off Off Off On *3 Hot Heater 522 *1 On On On On Hot Inflow Closed Open Open Closed *2 Valve 521 Hot Pump Outlet Closed Closed Closed Open *3 Valve 558 HX Hot Isolation Closed Open Open Open Closed Valve 556 Hot Drain Open Closed Closed Closed Closed Valve 553 *1 ON if HTS medium present; OFF if HTS medium not present *2 ON or OPEN if bypass flow to hot; OFF or CLOSED if bypass flow to warm *3 ON or OPEN if bypass flow to warm; OFF or CLOSED if bypass flow to hot

H. States of Cold-Side Loop

FIG. 26 is a state diagram illustrating cold-side loop (also referred to as CTS loop) states of a PHES system, including PHES system 1000, according to an example embodiment. The cold-side loop is the flow path of circulating CTS medium 690, for example, through CTS system 601 in FIG. 5 and, in some states, CHX system 600 in FIGS. 2, 3, 6A, and 6B.

The states in FIG. 26 occur sequentially, for the most part. The preferred sequential relationship of these states are indicated by directional arrows between states.

At Drained state 1156, CTS medium 690 in fluid paths, including heat exchangers, has been drained or is being drained into the CTS tanks (e.g., 610 and/or 620), preferably into a warm CTS tank (e.g., warm CTS tank 610). Preferably, no CTS pump is running once all CTS medium 690 has been drained.

At Standby state 1148, the cold-side loop is filled or filling with CTS medium 690 and is ready for CTS medium 690 to flow. Preferably, no CTS pump is running once the cold-side loop has been filled. If the loop is not already filled, then a flow rate from pumps 630 and/or 640 would be established in the appropriate direction in order to fill the fluid paths with CTS medium 690.

At Flow-to-Cold state 1150, the cold-side loop is configured to allow CTS medium 690 flow from warm CTS system 691 to cold CTS system 692 (e.g., from warm CTS tank 610 to cold CTS tank 620 in CTS system 601) via the cold-side heat exchanger(s) (e.g., CHX system 600). Warm pump 630 is on to deliver this flow. Cold pump 640, if bi-directional, can also be on to assist with pressure control. Bypass valve 605 is closed so that CTS medium 690 flows through CHX system 600.

At Flow-to-Warm state 1152, the cold-side loop is configured to allow CTS medium 690 flow from cold CTS system 692 to warm CTS system 691 (e.g., from cold CTS tank 620 to warm CTS tank 610 in CTS system 601) via the cold-side heat exchanger(s) (e.g., CHX system 600). Cold pump 640 is on to deliver this flow. Warm pump 630, if bi-directional, can also be on to assist with pressure control. Bypass valve 605 is closed so that CTS medium 690 flows through CHX system 600.

At Bypassed state 1154, CTS medium 590 is preferably flowing in the cold-side loop from cold CTS system 692 to warm CTS system (e.g., from cold CTS tank 620 to warm CTS tank 610 in CTS system 601), but not through the cold-side heat exchanger(s) (e.g., CHX system 600). Cold-side heat exchanger(s) are bypassed by opening bypass valve 605 and closing isolation valves 602, 603. Alternatively, in another embodiment, CTS medium 590 could flowing in the cold-side loop from warm CTS system to cold CTS system 692 (e.g., from warm CTS tank 610 to cold CTS tank 620 in CTS system 601), but not through the cold-side heat exchanger(s) (e.g., CHX system 600).

Table VII lists equipment status for cold-side loop states illustrated in FIG. 26 , in an embodiment of CTS system 601 where pumps 630, 640 are used for bi-directional pumping. Component references refer to example embodiments illustrated in, for example, FIGS. 2, 3, 5, 6A, and 6B and including CTS system 601 and CHX system 600, but the status may be applied to other configurations to accomplish the same hot-side loop states.

TABLE VII Status Drained Standby Flow-to-Cold Flow-to-Warm Bypassed Equipment 1156 1148 1150 1152 1154 Bypass Valve Closed Closed Closed Closed Open Valve 605 Inert Gas Purge *1 Closed Closed Closed Closed Valve 624 Cold Pump 640 Off Off On to Cold On to Warm *2 Cold Isolation Closed Open Open Open Closed Valve 602 Cold Tank Closed Open Open Open Open Valve 621 Cold Pump Isolation Closed Open Open Open Open Valve 641 Cold Pump Bypass Closed Closed Closed Closed Closed Valve 642 Cold Pump Isolation Closed Open Open Open Open Valve 643 Warm Pump 630 Off Off On to Cold On to Warm *2 Warm Isolation Closed Open Open Open Closed Valve 603 Warm Tank Closed Open Open Open Open Valve 611 Warm Pump Isolation Closed Open Open Open Open Valve 631 Warm Pump Bypass Closed Closed Closed Closed Closed Valve 632 Warm Pump Isolation Closed Open Open Open Open Valve 633 *1 OPEN until purge complete *2 ON-to-Warm if bypass flow to warm; ON-to-Cold if bypass flow to cold

Table VIII lists equipment status for cold-side loop states illustrated in FIG. 26 , in an embodiment of CTS system 601 where pumps 630, 640 are not used for bi-directional pumping. Component references refer to example embodiments illustrated in, for example, FIGS. 2, 3, 5, 6A, and 6B and including CTS system 601 and CHX system 600, but the status may be applied to other configurations to accomplish the same hot-side loop states.

TABLE VIII Status Drained Standby Flow-to-Cold Flow-to-Warm Bypassed 1156 1148 1150 1152 1154 Bypass Valve Closed Closed Closed Closed Open Valve 605 Inert Gas Purge *1 Closed Closed Closed Closed Valve 624 Cold Pump 640 Off Off Off On to Warm *2 Cold Isolation Closed Open Open Open Closed Valve 602 Cold Tank Closed Open Open Open Open Valve 621 Cold Pump Isolation Closed Open Closed Open *5 Valve 641 Cold Pump Bypass Closed Closed Open Closed *4 Valve 642 Cold Pump Isolation Closed Open Closed Open *5 Valve 643 Warm Pump 630 Off Off On to Cold On to Warm *3 Warm Isolation Closed Open Open Open Closed Valve 603 Warm Tank Closed Open Open Open Open Valve 611 Warm Pump Isolation Closed Open Open Closed *4 Valve 631 Warm Pump Bypass Closed Closed Closed Open *5 Valve 632 Warm Pump Isolation Closed Open Open Closed *4 Valve 633 *1 OPEN until purge complete *2 On-to-Warm if bypass flow to warm; OFF if bypass flow to cold *3 On-to-Cold if bypass flow to cold; OFF if bypass flow to warm *4 OPEN if bypass flow to cold; CLOSED if bypass flow to warm *5 CLOSED if bypass flow to cold; OPEN if bypass flow to warm

IV. Use Cases

This section describes transient “use cases” that can be implemented in a PHES system, including PHES system 1000 and the subsystems described herein. Each transient use case is a process or a transitionary sequence that the PHES system undergoes, and can be described by mode and/or state changes.

A. Cold Dry Standby to Hot Standby (PHES System Startup)

This use case is illustrated in FIG. 10 as the transition from Cold Dry Standby mode 1010 to Hot Standby mode 1008, and in FIG. 11 as the transition from operating state 1030 to operating state 1024.

B. Hot Standby to Charge (PHES System Startup)

This use case is illustrated in FIG. 10 as the transition from Hot Standby mode 1008 to Charge mode 1002, and in FIG. 11 as the transition from operating state 1024 to operating state 1014.

FIG. 19 further illustrates this use case. FIG. 19 is a state diagram illustrating operating and transitional states in a PHES system, including PHES system 1000, according to an example embodiment. These are example state transitions and other embodiments are possible as well. FIG. 19 illustrates transition from the HOT STANDBY state 1024 to CHARGE (GPT BASE) state 1014, with intermediate transitional states 1086, 1088, 1090 occurring sequentially in between. Each of the subsystem states is described elsewhere herein.

C. Hot Standby to Generation (PHES System Startup)

This use case is illustrated in FIG. 10 as the transition from Hot Standby mode 1008 to Generation mode 1004, and in FIG. 11 as the transition from operating state 1024 to operating state 1016.

FIG. 20 further illustrates this use case. FIG. 20 is a state diagram illustrating operating and transitional states in a PHES system, including PHES system 1000, according to an example embodiment. These are example state transitions and other embodiments are possible as well. FIG. 20 illustrates transition from the HOT STANDBY state 1024 to GENERATION (CPT BASE) state 1016, with intermediate transitional states 1094, 1096, 1098 occurring sequentially in between. Each of the subsystem states is described elsewhere herein.

D. Charge to Hot Turning (PHES System Shutdown)

This use case is illustrated in FIG. 10 as the transition from Charge mode 1002 to Hot Turning mode 1006, and in FIG. 11 as the transition from operating state 1014 to operating state 1018.

FIG. 21 further illustrates this use case. FIG. 21 is a state diagram illustrating operating and transitional states in a PHES system, including PHES system 1000, according to an example embodiment. These are example state transitions and other embodiments are possible as well. FIG. 21 illustrates transition from the CHARGE (GPT BASE) state 1014 to HOT TURNING (CPT SLOW ROLLING) state 1018, with intermediate transitional states 1102, 1104 occurring sequentially in between. Each of the subsystem states is described elsewhere herein.

E. Generation to Hot Turning (PHES System Shutdown)

This use case is illustrated in FIG. 10 as the transition from Generation mode 1004 to Hot Turning mode 1006, and in FIG. 11 as the transition from operating state 1016 to operating state 1022.

FIG. 22 further illustrates this use case. FIG. 22 is a state diagram illustrating operating and transitional states in a PHES system, including PHES system 1000, according to an example embodiment. These are example state transitions and other embodiments are possible as well. FIG. 22 illustrates transition from the GENERATION (CPT BASE) state 1016 to HOT TURNING (GPT SLOW ROLLING) state 1022, with intermediate transitional states 1108, 1110 occurring sequentially in between. Each of the subsystem states is described elsewhere herein.

F. Hot Standby to Cold Dry Standby (PHES System Shutdown)

This use case is illustrated in FIG. 10 as the transition from Hot Standby mode 1008 to Cold Dry Standby mode 1010 to, and in FIG. 11 as the transition from operating state 1024 to operating state 1030.

G. Charge to Generation (PHES System Mode Switch)

This use case is illustrated in FIG. 10 as the transition from Charge mode 1002 to Hot Turning mode 1006 to Generation mode 1004, and in FIG. 11 as the transition from operating state 1014 to operating state 1018 to operating state 1028.

FIG. 23 further illustrates this use case. FIG. 23 is a state diagram illustrating operating and transitional states in a PHES system, including PHES system 1000, according to an example embodiment. These are example state transitions and other embodiments are possible as well. FIG. 23 illustrates transition from the CHARGE (GPT BASE) state 1014 to HOT TURNING (CPT SLOW ROLLING) state 1018, with intermediate transitional states 1102, 1104 occurring sequentially in between. FIG. 23 further continues with illustration of the continuing transition from HOT TURNING (CPT SLOW ROLLING) state 1018 to GENERATION (CPT SLOW ROLL) state 1028, with intermediate transitional states 1116, 1118 occurring sequentially in between. Each of the subsystem states is described elsewhere herein. 

1. A pumped heat energy storage system, the system comprising: a charge compressor system (130); a charge turbine system (140); a generation compressor system (230); a generation turbine system (240); a hot-side heat exchanger (“HHX”) system (500); a recuperator heat exchanger (“RHX”) system (400); a cold-side heat exchanger (“CHX”) system (600); a hot-side thermal storage (“HTS”) system (501); a cold-side thermal storage (“CTS”) system (601); a working fluid loop (300) comprising: a first working fluid path arranged to circulate a working fluid through, in sequence, the charge compressor system, the HHX system, the RHX system, the charge turbine system, the CHX system, the RHX system, and back to the charge compressor system, and a second working fluid path arranged to circulate the working fluid through, in sequence, the generation compressor system, the RHX system, the HHX system, the generation turbine system, the RHX system, the CHX system, and back to the generation compressor system.
 2. The system of claim 1, further comprising: an inventory control system (300B), wherein the inventory control system includes a valve system operable to direct the working fluid from at least one of the first working fluid path or the second working fluid path into at least one tank system (310, 320), wherein the valve system is further operable to add the working fluid from the at least one tank system to at least one of the first working fluid path or the second working fluid path.
 3. The system of claim 1, further comprising: a third working fluid path arranged to recirculate at least a portion of the working fluid through the charge compressor system without circulating at least the portion of the working fluid through the HHX system, the RHX system, the charge turbine system, and the CHX system.
 4. The system of claim 3 further comprising a heat exchanger (132H) in the third working fluid path.
 5. The system of claim 1, further comprising: a third working fluid path arranged to recirculate at least a portion of the working fluid through the charge turbine system without circulating at least the portion of the working fluid through the CHX system, the RHX system, the charge compressor system, and the HHX system.
 6. The system of claim 1, further comprising: a third working fluid path arranged to recirculate at least a portion of the working fluid through the generation compressor system without circulating at least the portion of the working fluid through the RHX system, the HHX system, the generation turbine system, and the CHX system.
 7. The system of claim 1, further comprising: a third working fluid path arranged to recirculate at least a portion of the working fluid through the generation turbine system without circulating at least the portion of the working fluid through the RHX system, the CHX system, the generation compressor system, and the HHX system.
 8. The system of claim 7 further comprising a heat exchanger (242H) in the third working fluid path.
 9. The system of claim 7 further comprising a fan (242F) in the third working fluid path.
 10. The system of claim 1, further comprising: a bypass working fluid path arranged to circulate at least a portion of the working fluid from an outlet of the generation compressor system to an inlet of the generation turbine system without circulating at least the portion of the working fluid through the RHX system and the HHX system.
 11. The system of claim 1, further comprising: a bypass working fluid path arranged to circulate at least a portion of the working fluid from an outlet of the generation turbine system to an inlet of the CHX system without circulating at least the portion of the working fluid through the RHX system.
 12. The system of claim 1, further comprising: a bypass working fluid path arranged to circulate at least a portion of the working fluid from an outlet of the generation compressor system to a low-pressure side of the RHX system without circulating at least the portion of the working fluid through a high-pressure side of the RHX system, the HHX system, and the generation turbine system.
 13. The system of any one of claim 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, or 12, further comprising: a first charge isolation valve (131) in the first working fluid path between an outlet of the charge compressor system and an inlet of the HHX system; and a second charge isolation valve (141) in the first working fluid path between an outlet of the RHX system and an inlet of the charge turbine system.
 14. The system of any one of claim 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, or 12, further comprising: a first generation isolation valve (231) in the second working fluid path between an outlet of the generation compressor system and an inlet of the RHX system; and a second generation isolation valve (241) in the second working fluid path between an outlet of the HHX system and an inlet of the generation turbine system.
 15. The system of any one of claim 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, or 12, further comprising an ambient heat exchanger (“AHX”) system (700) arranged in the second working fluid path between an outlet of a low-pressure side of the RHX system and an inlet of the CHX system.
 16. A method of operating a pumped heat energy storage system, the method comprising: opening a first charge isolation valve (131) in a first working fluid path between an outlet of a charge compressor system (130) and an inlet of a hot-side heat exchanger (“HHX”) system (500); opening a second charge isolation valve (141) in the first working fluid path between an outlet of a recuperator heat exchanger (“RHX”) system (400) and an inlet of a charge turbine system (140); closing a first generation isolation valve (231) in a second working fluid path between an outlet of a generation compressor system (230) and an inlet of the RHX system; closing a second generation isolation valve (241) in the second working fluid path between an outlet of the HHX system and an inlet of a generation turbine system (240); and circulating a working fluid in the first working fluid path through, in sequence, the charge compressor system, the HHX system, the RHX system, the charge turbine system, a cold-side heat exchanger (“CHX”) system (600), the RHX system, and back to the charge compressor system.
 17. The method of claim 16, further comprising: opening a first inventory control valve (311) that releases at least a portion of the working fluid from the first working fluid path into at least one tank system (310); and closing the first inventory control valve, thus storing at least the portion of the working fluid in the at least one tank system.
 18. The method of claim 16, further comprising: opening a first inventory control valve (322) that adds an amount of the working fluid from at least one tank system (320) to the first working fluid path; and closing the first inventory control valve.
 19. The method of claim 16, further comprising: opening a valve (119) that allows at least a portion of the working fluid to recirculate through the charge compressor system without circulating at least the portion of the working fluid through the HHX system, the RHX system, the compressor turbine system, and the CHX system; and recirculating the at least the portion of the working fluid through the charge compressor system without circulating at least the portion of the working fluid through the HHX system, the RHX system, the compressor turbine system, and the CHX system.
 20. The method of claim 16, further comprising: opening a valve (232) that permits recirculation of a quantity of the working fluid through the generation compressor system without circulating the quantity of the working fluid through the RHX system, the HHX system, the generation turbine system, and the CHX system; and recirculating the quantity of the working fluid through the generation compressor system without circulating the quantity of the working fluid through the RHX system, the HHX system, the generation turbine system, and the CHX system.
 21. The method of claim 16, further comprising: opening a valve (242) that permits recirculation of a quantity of the working fluid through the generation turbine system without circulating the quantity of the working fluid through the RHX system, the CHX system, the generation compressor system, and the HHX system; and recirculating the quantity of the working fluid through the generation turbine system without circulating the quantity of the working fluid through the RHX system, the CHX system, the generation turbine system, and the HHX system.
 22. A method of operating a pumped heat energy storage system, the method comprising: closing a first charge isolation valve (131) in a first working fluid path between an outlet of a charge compressor system (130) and an inlet of a hot-side heat exchanger (“HHX”) system (500); closing a second charge isolation valve (141) in the first working fluid path between an outlet of a recuperator heat exchanger (“RHX”) system (400) and an inlet of a charge turbine system (140); opening a first generation isolation valve (231) in a second working fluid path between an outlet of a generation compressor system (230) and an inlet of the RHX system; opening a second generation isolation valve (241) in the second working fluid path between an outlet of the HHX system and an inlet of a generation turbine system (240); and circulating a working fluid in the second working fluid path through, in sequence, the generation compressor system, the RHX system, the HHX system, the generation turbine system, the RHX system, a cold-side heat exchanger (“CHX”) system (600), and back to the generation compressor system.
 23. The method of claim 22, further comprising: opening a first inventory control valve (311) that releases working fluid from the first working fluid path into at least one tank system (310); and closing the first inventory control valve, thus storing working fluid in the at least one tank system.
 24. The method of claim 22, further comprising: opening a first inventory control valve (322) that adds working fluid from at least one tank system (320) to the first working fluid path; and closing the first inventory control valve.
 25. The method of claim 22, further comprising: opening a valve (132) that permits recirculation of a quantity of the working fluid through the charge compressor system without circulating the quantity of the working fluid through the HHX system, the RHX system, the compressor turbine system, and the CHX system; and recirculating the quantity of the working fluid through the charge compressor system without circulating the quantity of the working fluid through the HHX system, the RHX system, the compressor turbine system, and the CHX system.
 26. The method of claim 22, further comprising: opening a valve (142) that permits recirculation of a quantity of the working fluid through the charge turbine system without circulating the quantity of the working fluid through the CHX system, the RHX system, the charge compressor system, and the HHX system; and recirculating the quantity of the working fluid through the charge turbine system without circulating the quantity of the working fluid through the CHX system, the RHX system, the charge compressor system, and the HHX system
 27. The method of claim 22, further comprising: opening a bypass valve (222) that permits circulation of a quantity of the working fluid from the outlet of the generation compressor system to the inlet of the generation turbine system without circulating the quantity of the working fluid through the RHX system and the HHX system; circulating the quantity of the working fluid from the outlet of the generation compressor system to the inlet of the generation turbine system without circulating the quantity of the working fluid through the RHX system and the HHX system; closing the first generation isolation valve; and closing the second generation isolation valve.
 28. The method of claim 22, further comprising: opening a bypass valve (401) that permits circulation of at least a portion of the working fluid from an outlet of the generation turbine system to an inlet of the CHX system without circulating at least the portion of the working fluid through the RHX system; and circulating at least a portion of the working fluid from the outlet of the generation turbine system to the inlet of the CHX system without circulating at least the portion of the working fluid through the RHX system.
 29. The method of claim 22, further comprising: opening a valve (229) that permits circulation of at least a portion of the working fluid from the outlet of the generation compressor system to a low-pressure side of the RHX system without circulating at least the portion of the working fluid through a high-pressure side of the RHX system, the HHX system, and the generation turbine system; and circulating at least the portion of the working fluid from the outlet of the generation compressor system to the low-pressure side of the RHX system without circulating at least the portion of the working fluid through the high-pressure side of the RHX system, the HHX system, and the generation turbine system.
 30. A pumped heat energy storage system, the system comprising: a charge compressor system (130); a charge turbine system (140); a working fluid loop (300) comprising a working fluid path arranged to circulate a working fluid through, in sequence, the charge compressor system, a hot-side heat exchanger (“HHX”) system (500), a recuperator heat exchanger (“RHX”) system (400), the charge turbine system, a cold-side heat exchanger (“CHX”) system (600), the RHX system, and back to the charge compressor system; and a first recirculation fluid path around the charge compressor system operable to recirculate at least a portion of the working fluid flowing through the charge compressor system from an outlet of the charge compressor system to an inlet of the charge compressor system.
 31. The system of claim 30, further comprising: a generation compressor system (230) distinct from the charge compressor system; a generation turbine system (240) distinct from the generation compressor system; and a second working fluid path arranged to circulate the working fluid through, in sequence, the generation compressor system, the RHX system, the HHX system, the generation turbine system, the RHX system, the CHX system, and back to the generation compressor system.
 32. The system of claim 30, further comprising a heat exchanger (132H) arranged in the first recirculation fluid path and in thermal contact with the working fluid recirculating in the first recirculation fluid path, wherein the heat exchanger is configured to remove heat from the working fluid.
 33. The system of claim 30, further comprising a valve (132) operable to allow or prevent recirculation of at least the portion of the working fluid in the first recirculation fluid path.
 34. The system of claim 30, further comprising: a second recirculation fluid path around the compressor system operable to recirculate at least a second portion of the working fluid flowing through the charge compressor system from an outlet of the charge compressor system to an inlet of the charge compressor system; and a valve (119) operable to allow or prevent recirculation of at least the second portion of the working fluid in the second recirculation fluid path.
 35. The system of claim 34, wherein the second recirculation fluid path permits a higher flow rate of working fluid than the first recirculation fluid path.
 36. A pumped heat energy storage system, the system comprising: a charge compressor system (130); a charge turbine system (140); a working fluid loop (300) comprising a working fluid path arranged to circulate a working fluid through, in sequence, the charge compressor system, a hot-side heat exchanger (“HHX”) system (500), a recuperator heat exchanger (“RHX”) system (400), the charge turbine system, a cold-side heat exchanger (“CHX”) system (600), the RHX system, and back to the charge compressor system; and a first recirculation fluid path around the charge turbine system operable to recirculate at least a portion of the working fluid flowing through the charge turbine system from an outlet of the charge turbine system to an inlet of the charge turbine system.
 37. The system of claim 36, further comprising: a generation compressor system (230) distinct from the charge compressor system; a generation turbine system (240) distinct from the generation compressor system; and a second working fluid path arranged to circulate the working fluid through, in sequence, the generation compressor system, the RHX system, the HHX system, the generation turbine system, the RHX system, the CHX system, and back to the generation compressor system.
 38. The system of claim 36, further comprising a fan (142F) arranged in the first recirculation fluid path, wherein the fan is operable to increase pressure of the working flowing through the first recirculation fluid path.
 39. The system of claim 38, further comprising a valve (142) operable to allow or prevent recirculation of at least the portion of the working fluid in the first recirculation fluid path.
 40. A pumped heat energy storage system, the system comprising: a generation compressor system (230); a generation turbine system (240); a working fluid loop (300) comprising a working fluid path arranged to circulate a working fluid through, in sequence, the generation compressor system, a recuperator heat exchanger (“RHX”) system (400), a hot-side heat exchanger (“HHX”) system (500), the generation turbine system, the RHX system, a cold-side heat exchanger (“CHX”) system (600), and back to the generation compressor system; and a first recirculation fluid path around the generation compressor system operable to recirculate at least a portion of the working fluid flowing through the generation compressor system from an outlet of the generation compressor system to an inlet of the generation compressor system.
 41. The system of claim 40, further comprising: a charge compressor system (130) distinct from the generation compressor system; a charge turbine system (140) distinct from the generation turbine system; and a second working fluid path arranged to circulate the working fluid through, in sequence, the charge compressor system, the HHX system, the RHX system, the charge turbine system, the CHX system, the RHX system, and back to the charge compressor system.
 42. The system of claim 40, further comprising a valve (232) operable to allow or prevent recirculation of at least the portion of the working fluid in the first recirculation fluid path.
 43. A pumped heat energy storage system, the system comprising: a generation compressor system (230); a generation turbine system (240); a working fluid loop (300) comprising a working fluid path arranged to circulate a working fluid through, in sequence, the generation compressor system, a recuperator heat exchanger (“RHX”) system (400), a hot-side heat exchanger (“HHX”) system (500), the generation turbine system, the RHX system, a cold-side heat exchanger (“CHX”) system (600), and back to the generation compressor system; and a first recirculation fluid path around the generation turbine system operable to recirculate at least a portion of the working fluid flowing through the generation turbine system from an outlet of the generation turbine system to an inlet of the generation turbine system.
 44. The system of claim 43, further comprising: a charge compressor system (130) distinct from the generation compressor system; a charge turbine system (140) distinct from the generation turbine system; and a second working fluid path arranged to circulate a working fluid through, in sequence, the charge compressor system, the HHX system, the RHX system, the charge turbine system, the CHX system, the RHX system, and back to the charge compressor system.
 45. The system of claim 43, further comprising a valve (242) operable to allow or prevent recirculation of at least the portion of the working fluid in the first recirculation fluid path.
 46. The system of claim 43, further comprising a fan (242F) arranged in the first recirculation fluid path, wherein the fan is operable to increase pressure of the working flowing through the first recirculation fluid path.
 47. The system of claim 43, further comprising a heat exchanger (242H) arranged in the first recirculation fluid path and in thermal contact with the working fluid recirculating in the first recirculation fluid path, wherein the heat exchanger is configured to remove heat from the working fluid.
 48. A pumped heat energy storage system, the system comprising: a generation compressor system (230); a generation turbine system (240); a working fluid loop (300) comprising a working fluid path arranged to circulate a working fluid through, in sequence, the generation compressor system, a recuperator heat exchanger (“RHX”) system (400), a hot-side heat exchanger (“HHX”) system (500), the generation turbine system, the RHX system, a cold-side heat exchanger (“CHX”) system (600), and back to the generation compressor system; and a first bypass fluid path arranged to accept at least a portion of the working fluid flowing through the working fluid path such that at least the portion of the working fluid instead flows from an outlet of the generation compressor system to an inlet of the generation turbine system, thereby bypassing a high-pressure side of the RHX system and the HHX system.
 49. The system of claim 48, further comprising: a charge compressor system (130) distinct from the generation compressor system; a charge turbine system (140) distinct from the generation turbine system; and a second working fluid path arranged to circulate the working fluid through, in sequence, the charge compressor system, the HHX system, the RHX system, the charge turbine system, the CHX system, the RHX system, and back to the charge compressor system.
 50. The system of claim 48, further comprising: a first valve (222) arranged in the first bypass fluid path between the outlet of the generation compressor system and the inlet to the generation turbine system, wherein the first valve is operable to allow or prevent flow of at least the portion of the working fluid in the first bypass fluid path.
 51. The system of claim 50, further comprising: a second valve (231) arranged in the working fluid path between the outlet of the generation compressor system and the inlet to the high-pressure side of the RHX system, wherein the second valve is operable to restrict flow of the working fluid in the working fluid path between the generation compressor system and the high-pressure side of the RHX system; and a third valve (241) arranged in the working fluid path between an outlet of the HHX system and the inlet to the generation turbine system, wherein the third valve is operable to restrict flow of the working fluid in the working fluid path between the HHX system and the generation turbine system.
 52. A pumped heat energy storage system, the system comprising: a generation compressor system (230); a generation turbine system (240); a working fluid loop (300) comprising a working fluid path arranged to circulate a working fluid through, in sequence, the generation compressor system, a recuperator heat exchanger (“RHX”) system (400), a hot-side heat exchanger (“HHX”) system (500), the generation turbine system, the RHX system, a cold-side heat exchanger (“CHX”) system (600), and back to the generation compressor system; and a first bypass fluid path arranged to accept at least a portion of the working fluid circulating through the working fluid path such that at least the portion of the working fluid instead flows from an outlet of the generation turbine system to an inlet of the CHX system, thereby bypassing a low-pressure side of the RHX system.
 53. The system of claim 52, further comprising: a charge compressor system (130) distinct from the generation compressor system; a charge turbine system (140) distinct from the generation turbine system; and a second working fluid path arranged to circulate the working fluid through, in sequence, the charge compressor system, the HHX system, the RHX system, the charge turbine system, the CHX system, the RHX system, and back to the charge compressor system.
 54. The system of claim 52, further comprising: an ambient heat exchanger (“AHX”) system (700), wherein the working fluid path is further arranged to circulate the working fluid through, in sequence, the generation compressor system, the RHX system, the HHX system, the generation turbine system, the RHX system, the AHX system, the CHX system, and back to the generation compressor system, and wherein the first bypass fluid path is further arranged such that at least the portion of the working fluid bypasses both the low-pressure side of the RHX system and the AHX system
 700. 55. The system of claim 52, further comprising: a first valve (401) arranged in the first bypass fluid path between the outlet of the generation turbine system and the inlet to the CHX system, wherein the first valve is operable to allow or prevent flow of at least the portion of the working fluid in the first bypass fluid path.
 56. The system of claim 52, further comprising: a second bypass fluid path arranged to accept at least a second portion of the working fluid circulating through the working fluid path such that at least the second portion of the working fluid instead flows from an outlet of the generation compressor system to an inlet of the generation turbine system, thereby bypassing a high-pressure side of the RHX system and the HHX system.
 57. The system of claim 56, further comprising: a second valve (222) arranged in the second bypass fluid path between the outlet of the generation compressor system and the inlet to the generation turbine system, wherein the second valve is operable to allow or prevent flow of at least the portion of the working fluid in the second bypass fluid path.
 58. The system of claim 57, further comprising: a third valve (231) arranged in the working fluid path between the outlet of the generation compressor system and the inlet to the high-pressure side of the RHX system, wherein the third valve is operable to restrict flow of the working fluid in the working fluid path between the generation compressor system and the high-pressure side of the RHX system; and a fourth valve (241) arranged in the working fluid path between an outlet of the HHX system and the inlet to the generation turbine system, wherein the fourth valve is operable to restrict flow of the working fluid in the working fluid path between the HHX system and the generation turbine system.
 59. A pumped heat energy storage system, the system comprising: a generation compressor system (230); a generation turbine system (240); a working fluid loop (300) comprising a working fluid path arranged to circulate a working fluid through, in sequence, the generation compressor system, a recuperator heat exchanger (“RHX”) system (400), a hot-side heat exchanger (“HHX”) system (500), the generation turbine system, the RHX system, a cold-side heat exchanger (“CHX”) system (600), and back to the generation compressor system; and a first bypass fluid path arranged to accept at least a portion of the working fluid circulating through the working fluid path such that at least the portion of the working fluid instead flows from an outlet of the generation compressor system to a low-pressure inlet of the RHX system, thereby bypassing a high-pressure side of the RHX system, the HHX system, and the generation turbine system.
 60. The system of claim 59, further comprising: a first valve (229) arranged in the first bypass fluid path between the outlet of the generation compressor system and the low-pressure inlet of the RHX system, wherein the first valve is operable to allow or prevent flow of at least the portion of the working fluid in the first bypass fluid path.
 61. A pumped heat energy storage system, the system comprising: a first working fluid path arranged to circulate a working fluid through, in sequence, a charge compressor system (130), a hot-side heat exchanger (“HHX”) system (500), a recuperator heat exchanger (“RHX”) system (400), a charge turbine system (140), a cold-side heat exchanger (“CHX”) system (600), the RHX system, and back to the charge compressor system, wherein a first high-pressure leg comprises a portion of the first fluid path between an outlet of the charge compressor system and an inlet of the charge turbine system, and wherein a first low-pressure leg comprises a portion of the first fluid path between an outlet of the charge turbine system and an inlet of the charge compressor system; a second working fluid path arranged to circulate a working fluid through, in sequence, a generation compressor system (230), the RHX system, the HHX system, a generation turbine system (240), the RHX system, the CHX system, and back to the generation compressor system, wherein a second high-pressure leg comprises a portion of the second fluid path between an outlet of the generation compressor system and an inlet of the generation turbine system, and wherein a second low-pressure leg comprises a portion of the second fluid path between an outlet of the generation turbine system and an inlet of the generation compressor system; and an inventory control system (“ICS”) comprising: a high-pressure tank system (320), a low-pressure tank system (310), a first valve (322) connected between the high-pressure tank system and at least one of the first low-pressure leg and the second low-pressure leg, and a second valve (311) connected between the low-pressure tank system and at least one of the first high-pressure leg and the second high-pressure leg.
 62. The system of claim 61, further comprising: a third valve (321) connected between the high-pressure tank system and at least one of the first high-pressure leg and the second high-pressure leg.
 63. The system of claim 61, further comprising: a third valve (312) connected between the low-pressure tank system and at least one of the first low-pressure leg and the second low-pressure leg.
 64. The system of claim 61, further comprising: a third valve (318) connected between the low-pressure tank system and at least one of the first high-pressure leg and the second high-pressure leg, wherein the second valve is a controlled proportional valve and the third valve is a dump valve, and wherein the third valve switches faster than the second valve and/or is larger than second valve.
 65. The system of claim 61, further comprising: an ICS working fluid compressor (303), wherein an inlet of the ICS working fluid compressor accepts the working fluid and an outlet of the ICS working fluid compressor is fluidly coupled to the high-pressure tank system.
 66. The system of claim 65, further comprising: a third valve (302) that is operable to isolate the ICS working fluid compressor from an external source of the working fluid.
 67. The system of claim 65, further comprising: a third valve (305) that is operable to alternately: (i) connect the ICS working fluid compressor to at least one of the first high-pressure leg and the second high-pressure leg, and (ii) to isolate the ICS working fluid compressor from at least one of the first high-pressure leg and the second high-pressure leg.
 68. The system of claim 65, further comprising: a third valve (304) that is operable to alternately: (i) connect the ICS working fluid compressor to at least one of the first low-pressure leg and the low high-pressure leg, and (ii) to isolate the ICS working fluid compressor from at least one of the first low-pressure leg and the second low-pressure leg.
 69. The system of claim 61, further comprising: a third valve (308) connected to at least one of the first low-pressure leg and the second low-pressure leg and operable to release the working fluid out of the pumped heat energy storage system.
 70. The system of claim 61, further comprising: a third valve (314) connected to at least one of the first high-pressure leg and the second high-pressure leg and operable to release the working fluid out of the pumped heat energy storage system.
 71. A method of operating a pumped heat energy storage system, the method comprising: circulating a working fluid through, in sequence, a first working fluid path comprising: a charge compressor system (130), a hot-side heat exchanger (“HHX”) system (500), a recuperator heat exchanger (“RHX”) system (400), a charge turbine system (140), a cold-side heat exchanger (“CHX”) system (600), the RHX system, and back to the charge compressor system, wherein a first high-pressure leg comprises a portion of the first fluid path between an outlet of the charge compressor system and an inlet of the charge turbine system, and wherein a first low-pressure leg comprises a portion of the first fluid path between an outlet of the charge turbine system and an inlet of the charge compressor system; and circulating the working fluid through, in sequence, a second working fluid path comprising: a generation compressor system (230), the RHX system, the HHX system, a generation turbine system (240), the RHX system, the CHX system, and back to the generation compressor system, wherein a second high-pressure leg comprises a portion of the second fluid path between an outlet of the generation compressor system and an inlet of the generation turbine system, and wherein a second low-pressure leg comprises a portion of the second fluid path between an outlet of the generation turbine system and an inlet of the generation compressor system.
 72. The method of claim 71, further comprising: opening a first valve (321) connected between a high-pressure tank system (320) and at least one of the first high-pressure leg and the second high-pressure leg, wherein at least a portion of the working fluid moves through the open first valve into the high-pressure tank system.
 73. The method of claim 71, further comprising: opening a first valve (305) connected between an inlet to an ICS working fluid compressor (303) and at least one of the first high-pressure leg and the second high-pressure leg; pressurizing, in the ICS working fluid compressor, the working fluid received via the first valve from at least one of the first high-pressure leg and the second high-pressure leg; and adding the pressurized working fluid to a high-pressure tank system (320).
 74. The method of claim 71, further comprising: opening a first valve (311, 318) connected between a low-pressure tank system (310) and at least one of the first high-pressure leg and the second high-pressure leg, wherein at least a portion of the working fluid moves through the open first valve into the low-pressure tank system.
 75. The method of claim 71, further comprising: opening a first valve (304) connected between an inlet to an ICS working fluid compressor (303) and at least one of the first low-pressure leg and the second low-pressure leg; pressurizing, in the ICS working fluid compressor, the working fluid received via the first valve from at least one of the first low-pressure leg and the second low-pressure leg; and adding the pressurized working fluid to a high-pressure tank system (320).
 76. The method of claim 71, further comprising: opening a first valve (312) connected between a low-pressure tank system (310) and at least one of the first low-pressure leg and the second low-pressure leg, wherein at least a portion of the working fluid moves through the open first valve into the low-pressure tank system.
 77. The method of claim 71, further comprising: opening a first valve (321) connected between a high-pressure tank system (320) and at least one of the first high-pressure leg and the second high-pressure leg, wherein at least a portion of the working fluid moves through the open first valve into at least one of the first high-pressure leg and the second high-pressure leg.
 78. The method of claim 71, further comprising: opening a first valve (322) connected between a high-pressure tank system (320) and at least one of the first low-pressure leg and the second low-pressure leg, wherein at least a portion of the working fluid moves through the open first valve into at least one of the first low-pressure leg and the second low-pressure leg.
 79. The method of any one of claim 72, 77, or 78 further comprising: pressurizing an ambient air in an ICS working fluid compressor (303); and adding the pressurized ambient air to the high-pressure tank system.
 80. The method of claim 71, further comprising: opening a first valve (312) connected between a low-pressure tank system (310) and at least one of the first low-pressure leg and the second low-pressure leg, wherein at least a portion of the working fluid moves through the open first valve into at least one of the first low-pressure leg and the second low-pressure leg.
 81. The method of any one of claim 72, 73, 74, 75, 76, 77, 78, or 80, further comprising: opening an evacuation valve (308) connected to at least one of the first low-pressure leg and the second low-pressure leg; and evacuating at least a portion of the working fluid through the evacuation valve to an external atmosphere.
 82. The method of any one of claim 72, 73, 74, 75, 76, 77, 78, or 80, further comprising: opening an evacuation valve (314) connected to at least one of the first high-pressure leg and the second high-pressure leg; and evacuating at least a portion of the working fluid through the evacuation valve to an external atmosphere.
 83. A pumped heat energy storage system, the system comprising: a charge compressor system (130); a charge turbine system (140); a generation compressor system (230); a generation turbine system (240); a hot-side heat exchanger (“HHX”) system (500); a recuperator heat exchanger (“RHX”) system (400); a cold-side heat exchanger (“CHX”) system (600); an ambient heat exchanger (“AHX”) system (700); a working fluid loop (300) comprising: a first working fluid path arranged to circulate a working fluid through, in sequence, the charge compressor system, the HHX system, the RHX system, the charge turbine system, the CHX system, the RHX system, and back to the charge compressor system, and a second working fluid path arranged to circulate the working fluid through, in sequence, the generation compressor system, the RHX system, the HHX system, the generation turbine system, the RHX system, the CHX system, and back to the generation compressor system; and a set of valves operable to: (i) in the second working fluid path, circulate the working fluid from the RHX system through the AHX system and to the CHX system when the set of valves are in a first state, (ii) in the second working fluid path, circulate the working fluid from the RHX system to the CHX system, bypassing the AHX system, when the set of valves are in a second state, and (iii) in the first working fluid path, circulate the working fluid from the CHX system to the RHX system, bypassing the AHX system, when the set of valves are in a third state.
 84. The system of claim 83, wherein the set of valves comprises: a bypass valve (323) located on a bypass working fluid path between the CHX system and the RHX system, bypassing the AHX system; and a first isolation valve (324) located on an AHX working fluid path between the AHX system and the RHX system.
 85. The system of claim 83, wherein the set of valves comprises: a bypass valve (323) located on a bypass working fluid path between the CHX system and the RHX system, bypassing the AHX system; and a first isolation valve (325) located on an AHX working fluid path between the AHX system and the RHX system.
 86. The system of any one of claim 84 or 85, wherein the first state comprises: the bypass valve is closed; and the first isolation valve is open.
 87. The system of any one of claim 84 or 85, wherein the second state comprises: the bypass valve is open; and the first isolation valve is closed.
 88. The system of any one of claim 84 or 85, wherein the third state comprises: the bypass valve is open; and the first isolation valve is closed.
 89. The system of claim 83, wherein the set of valves comprises: a bypass valve (323) located on a bypass working fluid path between the CHX system and the RHX system, bypassing the AHX system; a first isolation valve (324) located on an AHX working fluid path between the AHX system and the RHX system; and a second isolation valve (325) located on the AHX working fluid path between the AHX system and the CHX system.
 90. The system of claim 89, wherein the first state comprises: the bypass valve is closed; the first isolation valve is open; and the second isolation valve is open.
 91. The system of claim 89, wherein the second state comprises: the bypass valve is open; the first isolation valve is closed; and the second isolation valve is closed.
 92. The system of claim 89, wherein the third state comprises: the bypass valve is open; the first isolation valve is closed; and the second isolation valve is closed.
 93. The system of claim 83, wherein when the working fluid is circulating through the AHX system, the AHX system is configured to exhaust heat from the working fluid to an ambient environment.
 94. The system of claim 83, wherein when the working fluid is circulating through the AHX system, the AHX system is configured to exhaust heat from the working fluid to a heat sink.
 95. A method of operating a pumped heat energy storage system, the method comprising: opening a bypass valve (323) in a first working fluid path between an outlet of a cold-side heat exchanger (“CHX”) system (600) and an inlet of a recuperator heat exchanger (“RHX”) system (400); closing a first isolation valve in an AHX working fluid path between an ambient heat exchanger (“AHX”) system (700) and a portion of the first working fluid path between the outlet of the CHX system and the inlet of the RHX system; and circulating a working fluid in the first working fluid path through, in sequence, a charge compressor system (130), a hot-side heat exchanger (“HHX”) system (500), the RHX system, a charge turbine system (140), the CHX system, the bypass valve, the RHX system, and back to the charge compressor system.
 96. The method of claim 95, further comprising: closing a second isolation valve in the AHX working fluid path between the AHX system and the portion of the first working fluid path between the outlet of the CHX system and the inlet of the RHX system.
 97. A method of operating a pumped heat energy storage system, the method comprising: opening a bypass valve (323) in a first working fluid path between an inlet of a cold-side heat exchanger (“CHX”) system (600) and an outlet of a recuperator heat exchanger (“RHX”) system (400); closing a first isolation valve in an AHX working fluid path between an ambient heat exchanger (“AHX”) system (700) and a portion of the first working fluid path between the inlet of the CHX system and the outlet of the RHX system; and circulating a working fluid in the first working fluid path through, in sequence, a generation compressor system (230), the RHX system, a hot-side heat exchanger (“HHX”) system (500), a generation turbine system (240), the RHX system, the bypass valve, the CHX system, and back to the generation compressor system.
 98. The method of claim 97, further comprising: closing a second isolation valve in the AHX working fluid path between the AHX system and the portion of the first working fluid path between the inlet of the CHX system and the outlet of the RHX system.
 99. A method of operating a pumped heat energy storage system, the method comprising: closing a bypass valve (323) in a first working fluid path between an inlet of a cold-side heat exchanger (“CHX”) system (600) and an outlet of a recuperator heat exchanger (“RHX”) system (400); opening a first isolation valve in an AHX working fluid path between an ambient heat exchanger (“AHX”) system (700) and a portion of the first working fluid path between the inlet of the CHX system and the outlet of the RHX system; and circulating a working fluid in the first working fluid path through, in sequence, a generation compressor system (230), the RHX system, a hot-side heat exchanger (“HHX”) system (500), a generation turbine system (240), the RHX system, the AHX system, the CHX system, and back to the generation compressor system.
 100. The method of claim 99, further comprising: opening a second isolation valve in the AHX fluid path between the AHX system and the portion of the first working fluid path between the inlet of the CHX system and the outlet of the RHX system.
 101. The method of claim 99, wherein when the working fluid is circulating through the AHX system, the AHX system is configured to exhaust heat from the working fluid to an ambient environment.
 102. The system of claim 99, wherein when the working fluid is circulating through the AHX system, the AHX system is configured to exhaust heat from the working fluid to a heat sink.
 103. A pumped heat energy storage system, the system comprising: a charge compressor (130-1); a charge turbine (140-1); a drivetrain (150); a turning motor (121-1) configured to turn the charge compressor via the drivetrain at a first rotational speed; and a primary motor (110-1) configured to turn the compressor via the drivetrain at a second rotational speed causing circulation of a working fluid in a first working fluid path through, in sequence, the charge compressor, a hot-side heat exchanger (“HHX”) system (500), a recuperator heat exchanger (“RHX”) system (400), the charge turbine, a cold-side heat exchanger (“CHX”) system (600), the RHX system, and back to the charge compressor, and wherein the first rotational speed is less than the second rotational speed.
 104. The system of claim 103, further comprising a clutch (121-2) operatively positioned between the turning motor and the drivetrain.
 105. The system of claim 103, further comprising an overrunning clutch (121-2) operatively positioned between the turning motor and the drivetrain.
 106. The system of claim 103, further comprising an overrunning clutch (121-2) operatively positioned between the turning motor and the drivetrain, wherein the overrunning clutch is configured to disengage the turning motor from the drivetrain when a rotational speed of the drivetrain is higher than the first rotational speed.
 107. The system of claim 103, further comprising an overrunning clutch (121-2) operatively positioned between the turning motor and the drivetrain, wherein the overrunning clutch is configured to engage the turning motor with the drivetrain when a rotational speed of the drivetrain is at or below the first rotational speed.
 108. The system of claim 103, further comprising a gearbox (120-1) operatively positioned between the primary motor and the charge compressor.
 109. The system of claim 103, further comprising a gearbox (120-1) operatively positioned between the turning motor and the charge compressor.
 110. The system of claim 103, wherein the drivetrain includes a fixed connection between the turbine and the compressor.
 111. The system of claim 103, further comprising an electrical interconnect (15), wherein the electrical interconnect is configured to supply electrical power to the primary motor and/or the turning motor, and wherein the electrical interconnect is configured to receive electrical power from a generation system (210) that generates power from a generation turbine system (240) through which the working fluid flows.
 112. The system of claim 103, further comprising an electrical interconnect (15), wherein the electrical interconnect is configured to supply electrical power to the primary motor and/or the turning motor, and wherein the electrical interconnect is configured to receive electrical power from an electrical grid.
 113. A method of operating a pumped heat energy storage system, the method comprising: turning a charge compressor (130-1) with a turning motor (121-1) via a drivetrain (150) at a first rotational speed; and turning the charge compressor with a primary motor (110-1) via the drivetrain at a second rotational speed, causing circulation of a working fluid in a first working fluid path through, in sequence, the charge compressor, a hot-side heat exchanger (“HHX”) system (500), a recuperator heat exchanger (“RHX”) system (400), the charge turbine, a cold-side heat exchanger (“CHX”) system (600), the RHX system, and back to the charge compressor, and wherein the wherein the first rotational speed is less than the second rotational speed.
 114. The method of claim 113, further comprising disengaging the turning motor from the drivetrain via a clutch (121-2) operatively positioned between the turning motor and the drivetrain.
 115. The method of claim 113, further comprising disengaging the turning motor from the drivetrain via an overrunning clutch (121-2) operatively positioned between the turning motor and the drivetrain.
 116. The method of claim 113, further comprising disengaging the turning motor from the drivetrain via an overrunning clutch (121-2) operatively positioned between the turning motor and the drivetrain when a rotational speed of the drivetrain is higher than the first rotational speed.
 117. The method of claim 113, further comprising engaging the turning motor with the drivetrain via an overrunning clutch (121-2) operatively positioned between the turning motor and the drivetrain when a rotational speed of the drivetrain is at or below the first rotational speed.
 118. The method of claim 113, further comprising turning a gearbox (120-1) operatively positioned between the primary motor and the compressor.
 119. The method of claim 113, further comprising turning a gearbox (120-1) operatively positioned between the turning motor and the compressor.
 120. The method of claim 113, wherein the drivetrain includes a fixed connection between the turbine and the compressor.
 121. The method of claim 113, further comprising supplying electrical power to the primary motor and/or the turning motor from an electrical interconnect (15), wherein the electrical interconnect receives electrical power from a generation system (210) that generates power from a generation turbine system (240) through which the working fluid flows.
 122. The method of claim 113, further comprising supplying electrical power to the primary motor and/or the turning motor from an electrical interconnect (15), wherein the electrical interconnect receives electrical power from an electrical grid.
 123. A method of operating a pumped heat energy storage system, the method comprising: turning a charge compressor (130-1) with a turning motor (121-1) via a first drivetrain (150) at a first rotational speed, wherein the first drivetrain is coupled to a primary motor (110-1); and turning a generator (210-1) with a generation turbine (240-1) via a second drivetrain at a second rotational speed via circulation of a working fluid in a first working fluid path through, in sequence, the generation compressor, a recuperator heat exchanger (“RHX”) system (400), a hot-side heat exchanger (“HHX”) system (500), the generation turbine, the RHX system, a cold-side heat exchanger (“CHX”) system (600), and back to the generation compressor, wherein the first rotational speed is less than the second rotational speed.
 124. A pumped heat energy storage system, the system comprising: a generation compressor (230-1); a generation turbine (240-1); a drivetrain (250); a turning motor (221-1) configured to turn the generation compressor via the drivetrain at a first rotational speed; and a generator (210-1) configured to be turned by the generation turbine via the drivetrain at a second rotational speed via circulation of a working fluid in a first working fluid path through, in sequence, the generation compressor, a recuperator heat exchanger (“RHX”) system (400), a hot-side heat exchanger (“HHX”) system (500), the generation turbine, the RHX system, a cold-side heat exchanger (“CHX”) system (600), and back to the generation compressor, and wherein the first rotational speed is less than the second rotational speed.
 125. The system of claim 124, wherein the generator is further configured to alternately act as a motor configured to turn the generation compressor via the drivetrain.
 126. The system of claim 124, further comprising a clutch (221-2) operatively positioned between the turning motor and the drivetrain.
 127. The system of claim 124, further comprising an overrunning clutch (221-2) operatively positioned between the turning motor and the drivetrain, wherein the overrunning clutch is configured to disengage the turning motor from the drivetrain when a rotational speed of the drivetrain is higher than the first rotational speed.
 128. The system of claim 124, further comprising an overrunning clutch (221-2) operatively positioned between the turning motor and the drivetrain, wherein the overrunning clutch is configured to engage the turning motor with the drivetrain when a rotational speed of the drivetrain is at or below the first rotational speed.
 129. The system of claim 124, further comprising a gearbox (220-1) operatively positioned between the generator and the generation turbine.
 130. The system of claim 124, further comprising a gearbox (220-1) operatively positioned between the turning motor and the generation compressor.
 131. The system of claim 124, wherein the drivetrain includes a fixed connection between the generation turbine and the generation compressor.
 132. The system of claim 124, further comprising an electrical interconnect (21), wherein the electrical interconnect is configured to receive electrical power from the generator and wherein the electrical interconnect is configured to send the electrical power to a charge powertrain system (100) to turn a charge compressor system (130) through which the working fluid flows.
 133. The system of claim 124, further comprising an electrical interconnect (21), wherein the electrical interconnect is configured to receive electrical power from the generator, and wherein the electrical interconnect is configured to send the electrical power to an electrical grid.
 134. A method of operating a pumped heat energy storage system, the method comprising: turning a generation compressor (230-1) with a turning motor (221-1) via a drivetrain (250) at a first rotational speed; and turning a generator (210-1) with a generation turbine (240-1) via the drivetrain at a second rotational speed via circulation of a working fluid in a first working fluid path through, in sequence, the generation compressor, a recuperator heat exchanger (“RHX”) system (400), a hot-side heat exchanger (“HHX”) system (500), the generation turbine, the RHX system, a cold-side heat exchanger (“CHX”) system (600), and back to the generation compressor, and wherein the wherein the first rotational speed is less than the second rotational speed.
 135. The system of claim 134, further comprising turning, via the drivetrain, the generation compressor with the generator acting as a motor.
 136. The method of claim 134, further comprising disengaging the turning motor from the drivetrain via a clutch (221-2) operatively positioned between the turning motor and the drivetrain.
 137. The method of claim 134, further comprising disengaging the turning motor from the drivetrain via an overrunning clutch (221-2) operatively positioned between the turning motor and the drivetrain when a rotational speed of the drivetrain is higher than the first rotational speed.
 138. The method of claim 134, further comprising engaging the turning motor with the drivetrain via an overrunning clutch (221-2) operatively positioned between the turning motor and the drivetrain when a rotational speed of the drivetrain is at or below the first rotational speed.
 139. The method of claim 134, further comprising turning a gearbox (220-1) operatively positioned between the generator and the generation turbine.
 140. The method of claim 134, further comprising turning a gearbox (220-1) operatively positioned between the turning motor and the generation compressor.
 141. The method of claim 134, wherein the drivetrain includes a fixed connection between the turbine and the compressor.
 142. The method of claim 134, further comprising supplying electrical power from the generator to an electrical interconnect (21), wherein the electrical interconnect supplies the electrical power to a charge powertrain system (100) for turning a charge compressor system (130) through which the working fluid flows.
 143. The method of claim 134, further comprising supplying electrical power from the generator to an electrical interconnect (21), wherein the electrical interconnect supplies electrical power to an electrical grid.
 144. A method of operating a pumped heat energy storage system, the method comprising: turning a generation compressor (230-1) with a turning motor (221-1) via a first drivetrain (250) at a first rotational speed, wherein the first drivetrain is coupled to a generator (210-1); and turning a charge compressor (130-1) with a primary motor (110-1) via a second drivetrain (150) at a second rotational speed, causing circulation of a working fluid in a first working fluid path through, in sequence, the charge compressor, a hot-side heat exchanger (“HHX”) system (500), a recuperator heat exchanger (“RHX”) system (400), the charge turbine, a cold-side heat exchanger (“CHX”) system (600), the RHX system, and back to the charge compressor, and wherein the first rotational speed is less than the second rotational speed.
 145. A method of operating a pumped heat energy storage system, the method comprising: circulating a working fluid through, in sequence, a first working fluid path comprising: a charge compressor system (130), a hot-side heat exchanger (“HHX”) system (500), a recuperator heat exchanger (“RHX”) system (400), a charge turbine system (140), a cold-side heat exchanger (“CHX”) system (600), the RHX system, and back to the charge compressor system; in a first fluid path, flowing a first quantity of a hot-side thermal storage (“HTS”) medium (590) from a warm HTS tank (510) through the HHX system to a hot HTS tank (520), wherein the first quantity of the HTS medium is in thermal contact with the working fluid circulating through the HHX system; and in a second fluid path, flowing a second quantity of the HTS medium from the hot HTS tank to the warm HTS tank, wherein the second quantity of the HTS medium does not flow through the HHX system.
 146. The method of claim 145, further comprising: circulating the working fluid through, in sequence, a second working fluid path comprising: a generation compressor system (230), the RHX system, the HHX system, a generation turbine system (240), the RHX system, the CHX system, and back to the generation compressor system; and in a third fluid path, flowing a third quantity of the HTS medium from the hot HTS tank through the HHX system to the warm HTS tank, wherein the third quantity of the HTS medium is in thermal contact with the working fluid circulating through the HHX system.
 147. The method of claim 146, wherein the second quantity of the HTS medium is equivalent to a difference between the first quantity of the HTS medium and the third quantity of the HTS medium.
 148. The method of claim 145, wherein the step of, in the second fluid path, flowing the second quantity of the HTS medium from the hot HTS tank to the warm HTS tank comprises: closing an isolation valve (555) in the first fluid path between the warm HTS tank and the HHX system; closing an isolation valve (556) in the first fluid path between the hot HTS tank and the HHX system; and opening a bypass valve (551) in the second fluid path between the hot HTS tank and the warm HTS tank.
 149. The method of claim 145, further comprising: ceasing flow of the HTS medium in the first fluid path; and draining the HTS medium remaining in the first fluid path to the warm HTS tank (510) and/or the hot HTS tank (520).
 150. A method of operating a pumped heat energy storage system, the method comprising: circulating a working fluid through, in sequence, a first working fluid path comprising: a charge compressor system (130), a hot-side heat exchanger (“HHX”) system (500), a recuperator heat exchanger (“RHX”) system (400), a charge turbine system (140), a cold-side heat exchanger (“CHX”) system (600), the RHX system, and back to the charge compressor system; in a first fluid path, flowing a first quantity of a hot-side thermal storage (“HTS”) medium (590) from a warm HTS tank (510) through the HHX system to a hot HTS tank (520), wherein the first quantity of the HTS medium is in thermal contact with the working fluid circulating through the HHX system; and in a second fluid path, flowing a second quantity of the HTS medium from the warm HTS tank to the hot HTS tank, wherein the second quantity of the HTS medium does not flow through the HHX system.
 151. The method of claim 150, further comprising: circulating the working fluid through, in sequence, a second working fluid path comprising: a generation compressor system (230), the RHX system, the HHX system, a generation turbine system (240), the RHX system, the CHX system, and back to the generation compressor system; and in a third fluid path, flowing a third quantity of the HTS medium from the hot HTS tank through the HHX system to the warm HTS tank, wherein the third quantity of the HTS medium is in thermal contact with the working fluid circulating through the HHX system.
 152. The method of claim 151, wherein the second quantity of the HTS medium is equivalent to a difference between the third quantity of the HTS medium and the first quantity of the HTS medium.
 153. The method of claim 150, wherein the step of, in the second fluid path, flowing a second quantity of the HTS medium from the warm HTS tank to the hot HTS tank comprises: enabling the flow of the second quantity of the HTS medium from the warm HTS tank to the hot HTS tank via a bypass valve (551) in the second fluid path between the hot HTS tank and the warm HTS tank.
 154. The method of claim 153, further comprising: restricting the flow in the first fluid path via an isolation valve (555) between the warm HTS tank and the HHX system; and restricting the flow in the first fluid path via an isolation valve (556) between the hot HTS tank and the HHX system.
 155. The method of claim 150, further comprising: ceasing flow of the HTS medium in the first fluid path; and draining the HTS medium remaining in the first fluid path to the warm HTS tank (510) and/or the hot HTS tank (520).
 156. A method of operating a pumped heat energy storage system, the method comprising: circulating a working fluid through, in sequence, a first working fluid path comprising: a charge compressor system (130), a hot-side heat exchanger (“HHX”) system (500), a recuperator heat exchanger (“RHX”) system (400), a charge turbine system (140), a cold-side heat exchanger (“CHX”) system (600), the RHX system, and back to the charge compressor system; in a first fluid path, flowing a first quantity of a cold-side thermal storage (“CTS”) medium (690) from a warm CTS tank (610) through the CHX system to a cold CTS tank (620), wherein the first quantity of the CTS medium is in thermal contact with the working fluid circulating through the CHX system; and in a second fluid path, flowing a second quantity of the CTS medium from the cold CTS tank to the warm CTS tank, wherein the second quantity of the CTS medium does not flow through the CHX system.
 157. The method of claim 156, further comprising: circulating the working fluid through, in sequence, a second working fluid path comprising: a generation compressor system (230), the RHX system, the HHX system, a generation turbine system (240), the RHX system, the CHX system, and back to the generation compressor system; and in a third fluid path, flowing a third quantity of the CTS medium from the cold CTS tank through the CHX system to the warm CTS tank, wherein the third quantity of the CTS medium is in thermal contact with the working fluid circulating through the CHX system.
 158. The method of claim 157, wherein the second quantity of the CTS medium is equivalent to a difference between the first quantity of the CTS medium and the third quantity of the CTS medium.
 159. The method of claim 156, wherein the step of, in the second fluid path, flowing a second quantity of the CTS medium from the cold CTS tank to the warm CTS tank comprises: enabling of the second quantity of the CTS medium from the cold CTS tank to the warm CTS tank via a bypass valve (605) in the second fluid path between the cold CTS tank and the warm CTS tank.
 160. The method of claim 159, further comprising: closing an isolation valve (603) in the first fluid path between the warm CTS tank and the CHX system; and closing an isolation valve (602) in the first fluid path between the cold CTS tank and the CHX system.
 161. The method of claim 156, further comprising: ceasing flow of the CTS medium in the first fluid path; and draining the CTS medium remaining in the first fluid path to the warm CTS tank (610) and/or the hot CTS tank (620).
 162. A method of operating a pumped heat energy storage system, the method comprising: circulating a working fluid through, in sequence, a first working fluid path comprising: a charge compressor system (130), a hot-side heat exchanger (“HHX”) system (500), a recuperator heat exchanger (“RHX”) system (400), a charge turbine system (140), a cold-side heat exchanger (“CHX”) system (600), the RHX system, and back to the charge compressor system; in a first fluid path, flowing a first quantity of a cold-side thermal storage (“CTS”) medium (690) from a warm CTS tank (610) through the CHX system to a cold CTS tank (620), wherein the first quantity of the CTS medium is in thermal contact with the working fluid circulating through the CHX system; and in a second fluid path, flowing a second quantity of the CTS medium from the warm CTS tank to the cold CTS tank, wherein the second quantity of the CTS medium does not flow through the CHX system.
 163. The method of claim 162, further comprising: circulating the working fluid through, in sequence, a second working fluid path comprising: a generation compressor system (230), the RHX system, the HHX system, a generation turbine system (240), the RHX system, the CHX system, and back to the generation compressor system; and in a third fluid path, flowing a third quantity of the CTS medium from the cold CTS tank through the CHX system to the warm CTS tank, wherein the third quantity of the CTS medium is in thermal contact with the working fluid circulating through the CHX system.
 164. The method of claim 163, wherein the second quantity of the CTS medium is equivalent to a difference between the third quantity of the CTS medium and the first quantity of the CTS medium.
 165. The method of claim 162, wherein the step of, in the second path, flowing a second quantity of the CTS medium from the warm CTS tank to the cold CTS tank comprises: enabling the flow of the second quantity of the CTS medium from the warm CTS tank to the cold CTS tank via a bypass valve (605) in the first fluid path between the warm CTS tank and the cold CTS tank.
 166. The method of claim 165, further comprising: restricting the flow in the first fluid path via an isolation valve (602) between the cold CTS tank and the CHX system; and restricting the flow in the first fluid path via an isolation valve (603) between the CHX system and the warm CTS tank.
 167. The method of claim 162, further comprising: ceasing flow of the CTS medium in the first fluid path; and draining the CTS medium remaining in the first fluid path to the warm CTS tank (610) and/or the hot CTS tank (620).
 168. A method of operating a pumped heat energy storage system, the method comprising: circulating a working fluid through, in sequence, a first working fluid path comprising: a charge compressor system (130), a hot-side heat exchanger (“HHX”) system (500), a recuperator heat exchanger (“RHX”) system (400), a charge turbine system (140), a cold-side heat exchanger (“CHX”) system (600), the RHX system, and back to the charge compressor system; and pumping a cold-side thermal storage (“CTS”) medium (690) with a first pump (630), causing the CTS medium to flow from a warm CTS tank (610), through the CHX system, through a bypass valve (642), and to a cold CTS tank (620), wherein the flowing CTS medium is in thermal contact with the working fluid circulating through the CHX system, and wherein the bypass valve permits flow of the CTS medium around a second pump (640).
 169. The method of claim 168, wherein the first pump is arranged in a first flow path of the CTS medium from the warm CTS tank to the CHX system.
 170. The method of claim 169, further comprising: opening one or more isolation valves (641, 643), wherein in a closed state the one or more isolation valves isolate the second pump from flow of the CTS medium, and wherein in an open state the one or more isolation valves expose the second pump to flow of the CTS medium; and pumping the CTS medium from the CHX system to the cold CTS tank with the second pump, wherein, when pumping the CTS medium with the second pump, the CTS medium in the CHX system is at a lower pressure than if pumping the CTS medium with the first pump alone.
 171. The method of claim 170, wherein the second pump is arranged in a second flow path of the CTS medium from the CHX system to the cold CTS tank.
 172. The method of claim 170, wherein, when pumping the CTS medium with the second pump, the CTS medium in the CHX system is at a lower pressure than a pressure of the working fluid circulating in the CHX system.
 173. The method of claim 171, wherein an isolation valve (641) of the one or more isolation valves is arranged in the second flow path of the CTS medium between the CHX system and the second pump.
 174. The method of claim 171, wherein an isolation valve (643) of the one or more isolation valves is arranged in the second flow path of the CTS medium between the second pump and the cold CTS tank.
 175. The method of claim 168, further comprising: circulating the working fluid through, in sequence, a second working fluid path comprising: a generation compressor system (230), the RHX system, the HHX system, a generation turbine system (240), the RHX system, the CHX system, and back to the generation compressor system; and pumping the CTS medium with the second pump, causing the CTS medium to flow from the cold CTS tank, through the CHX system, through a bypass valve (632), and to the warm CTS tank, wherein the flowing CTS medium is in thermal contact with the working fluid circulating through the CHX system, and wherein the bypass valve permits flow of the CTS medium around the first pump.
 176. The method of claim 175, further comprising: opening one or more isolation valves (631, 633), wherein in a closed state the one or more isolation valves isolate the first pump from flow of the CTS medium, and wherein in an open state the one or more isolation valves expose the first pump to flow of the CTS medium; and pumping the CTS medium from the CHX system to the warm CTS tank with the first pump, wherein, when pumping the CTS medium with the first pump, the CTS medium in the CHX system is at a lower pressure than if pumping the CTS medium with the second pump alone.
 177. The method of claim 168, further comprising: flowing a pressurized inert gas into a CTS medium flow path through the CHX system; continuing to flow the pressurized inert gas until the CHX system is purged of the CTS medium.
 178. A method of operating a pumped heat energy storage system, the method comprising: circulating the working fluid through, in sequence, a first working fluid path comprising: a generation compressor system (230), a recuperator heat exchanger (“RHX”) system (400), a hot-side heat exchanger (“HHX”) system (500), a generation turbine system (240), the RHX system, a cold-side heat exchanger (“CHX”) system (600), and back to the generation compressor system; and pumping a cold-side thermal storage (“CTS”) medium with a first pump (640), causing the CTS medium to flow from a cold CTS tank (620), through the CHX system, through a bypass valve (632), and to a warm CTS tank (610), wherein the flowing CTS medium is in thermal contact with the working fluid circulating through the CHX system, and wherein the bypass valve permits flow of the CTS medium around a second pump (630).
 179. The method of claim 178, wherein the first pump is arranged in a first flow path of the CTS medium from the cold CTS tank to the CHX system.
 180. The method of claim 179, further comprising: opening one or more isolation valves (631, 633), wherein in a closed state the one or more isolation valves isolate the second pump from flow of the CTS medium, and wherein in an open state the one or more isolation valves expose the second pump to flow of the CTS medium; and pumping the CTS medium from the CHX system to the warm CTS tank with the second pump, wherein, when pumping the CTS medium with the second pump, the CTS medium in the CHX system is at a lower pressure than if pumping the CTS medium with the first pump alone.
 181. The method of claim 180, wherein the second pump is arranged in a second flow path of the CTS medium from the CHX system to the warm CTS tank.
 182. The method of claim 180, wherein, when pumping the CTS medium with the second pump, the CTS medium in the CHX system is at a lower pressure than a pressure of the working fluid circulating in the CHX system.
 183. The method of claim 181, wherein an isolation valve (631) of the one or more isolation valves is arranged in the second flow path of the CTS medium between the CHX system and the second pump.
 184. The method of claim 181, wherein an isolation valve (633) of the one or more isolation valves is arranged in the second flow path of the CTS medium between the second pump and the warm CTS tank.
 185. The method of claim 178, further comprising: circulating a working fluid through, in sequence, a second working fluid path comprising: a charge compressor system (130), the HHX system, the RHX system, a charge turbine system (140), the CHX system, the RHX system, and back to the charge compressor system; and pumping the CTS medium with the second pump, causing the CTS medium to flow from the warm CTS tank, through the CHX system, through a bypass valve (642), and to the cold CTS tank, wherein the flowing CTS medium is in thermal contact with the working fluid circulating through the CHX system, and wherein the bypass valve permits flow of the CTS medium around the first pump.
 186. The method of claim 185, further comprising: opening one or more isolation valves (641, 643), wherein in a closed state the one or more isolation valves isolate the first pump from flow of the CTS medium, and wherein in an open state the one or more isolation valves expose the first pump to flow of the CTS medium; and pumping the CTS medium from the CHX system to the cold CTS tank with the first pump, wherein, when pumping the CTS medium with the first pump, the CTS medium in the CHX system is at a lower pressure than if pumping the CTS medium with the second pump alone.
 187. The method of claim 178, further comprising: flowing a pressurized inert gas into a CTS medium flow path through the CHX system; continuing to flow the pressurized inert gas until the CHX system is purged of the CTS medium.
 188. A method of operating a pumped heat energy storage system (“PHES system”), the method comprising: operating the PHES system in a charge mode (1002), the charge mode operation comprising: turning a charge compressor (130-1) at a first charge-mode operating speed via a primary motor (110-1), and circulating a working fluid through, in sequence, a first working fluid path comprising: the charge compressor, a hot-side heat exchanger (“HHX”) (500-1), a recuperator heat exchanger (“RHX”) (400-1), a charge turbine (140-1), a cold-side heat exchanger (“CHX”) (600-1), the RHX, and back to the charge compressor, wherein the circulating working fluid is in thermal contact with a cold-side thermal storage (“CTS”) medium (690) and a hot-side thermal storage (“HTS”) medium (590), and wherein the circulating working fluid transfers thermal energy from the CTS medium to the HTS medium; and operating the PHES system in a hot turning mode (1006), the hot turning mode operation comprising: turning the charge compressor at a charge compressor slow-rolling speed, wherein the charge compressor slow-rolling speed is less than the first charge-mode operating speed.
 189. The method of claim 188, wherein the hot turning mode operation further comprises: wherein the working fluid is not transferring thermal energy between the CTS medium and the HTS medium.
 190. The method of claim 188, wherein the hot turning mode operation further comprises: preventing circulation of the working fluid through the first working fluid path.
 191. The method of claim 188, wherein the hot turning mode operation further comprises: recirculating a first portion of the working fluid through the charge compressor without circulating the first portion of the working fluid through the HHX system, the RHX system, the compressor turbine system, and the CHX system.
 192. The method of any one of claim 188, 189, 190, or 191, wherein the method further comprises transitioning the PHES system from the charge mode operation to the hot turning mode operation.
 193. The method of any one of claim 188, 189, 190, or 191, wherein the method further comprises transitioning the PHES system from the hot turning mode operation to the charge mode operation.
 194. The method of any one of claim 188, 189, 190, or 191, wherein turning the charge compressor at the charge compressor slow-rolling speed comprises turning the charge compressor via a turning motor, wherein the turning motor is distinct from the primary motor.
 195. The method of any one of claim 188, 189, 190, or 191, wherein the charge mode operation further comprises turning the charge turbine at a second charge-mode operating speed; and wherein the hot turning mode operation further comprises: turning the charge turbine at a charge turbine slow-rolling speed, wherein the charge turbine slow-rolling speed is less than the second charge-mode operating speed; and recirculating a second portion of the working fluid through the charge turbine without circulating the second portion of the working fluid through the CHX system, the RHX system, the charge compressor system, and the HHX system.
 196. The method of any one of claim 188, 189, 190, or 191, wherein the charge mode operation further comprises flowing the CTS medium through the CHX and flowing the HTS medium through the HHX, and wherein the hot turning mode operation further comprises not flowing the CTS medium through the CHX and not flowing the HTS medium through the HHX.
 197. The method of any one of claim 188, 189, or 191, wherein the hot turning mode operation further comprises not circulating the working fluid through the first working fluid path.
 198. The method of any one of claim 188, 190, or 191, wherein the hot turning mode operation further comprises not transferring thermal energy between the CTS medium and the HTS medium.
 199. The method of any one of claim 188, 189, 190, or 191, wherein the hot turning mode operation further comprises: turning a generation compressor (230-1) at a generation compressor slow-rolling speed; and recirculating a second portion of the working fluid through the generation compressor without circulating the second portion of the working fluid through the RHX system, the HHX system, a generation turbine (240-1), and the CHX system.
 200. A method of operating a pumped heat energy storage system (“PHES system”), the method comprising: operating the PHES system in a charge mode (1002), the charge mode operation comprising: turning a charge compressor (130-1) at a first charge-mode operating speed via a primary motor (110-1), and circulating a working fluid through, in sequence, a first working fluid path comprising: the charge compressor, a hot-side heat exchanger (“HHX”) (500-1), a recuperator heat exchanger (“RHX”) (400-1), a charge turbine (140-1), a cold-side heat exchanger (“CHX”) (600-1), the RHX, and back to the charge compressor, wherein the circulating working fluid is in thermal contact with a cold-side thermal storage (“CTS”) medium (690) and a hot-side thermal storage (“HTS”) medium (590), and wherein the circulating working fluid transfers thermal energy from the CTS medium to the HTS medium; and operating the PHES system in a hot turning mode (1006), the hot turning mode operation comprising: turning a generation compressor (230-1) at a generation compressor slow-rolling speed.
 201. The method of claim 200, wherein the hot turning mode operation further comprises: wherein the working fluid is not transferring thermal energy between the CTS medium and the HTS medium.
 202. The method of claim 200, wherein the hot turning mode operation further comprises: preventing circulation of the working fluid through the first working fluid path.
 203. The method of claim 200, wherein the hot turning mode operation further comprises: preventing circulation of the working fluid through a second working fluid path comprising, in sequence: the generation compressor, the RHX, the HHX, a generation turbine (240-1), the RHX, the CHX, and back to the generation compressor.
 204. The method of claim 200, wherein the hot turning mode operation further comprises: recirculating a portion of the working fluid through the generation compressor without circulating the second portion of the working fluid through the RHX system, the HHX system, a generation turbine (240-1), and the CHX system.
 205. A method of operating a pumped heat energy storage system (“PHES system”), the method comprising: operating the PHES system in a generation mode (1004), the generation mode operation comprising: circulating a working fluid through, in sequence, a first working fluid path comprising: a generation compressor (230-1), a recuperator heat exchanger (“RHX”) (400-1), a hot-side heat exchanger (“HHX”) (500-1), a generation turbine (240-1), the RHX, a cold-side heat exchanger (“CHX”) (600-1), and back to the generation compressor, wherein the circulating working fluid is in thermal contact with a cold-side thermal storage (“CTS”) medium (690) and a hot-side thermal storage (“HTS”) medium (590), wherein the circulating working fluid transfers thermal energy from the HTS medium to the CTS medium, and turning a generator (210-1) via the generation turbine operating at a first generation-mode operating speed; and operating the PHES system in a hot turning mode (1006), the hot turning mode operation comprising: turning the generation turbine at a generation turbine slow-rolling speed, wherein the generation turbine slow-rolling speed is less than the first generation-mode operating speed.
 206. The method of claim 205, wherein the hot turning mode operation further comprises: wherein the working fluid is not transferring thermal energy between the HTS medium and the CTS medium.
 207. The method of claim 205, wherein the hot turning mode operation further comprises: preventing circulation of the working fluid through the first working fluid path.
 208. The method of claim 205, wherein the hot turning mode operation further comprises: recirculating a first portion of the working fluid through the generation turbine without circulating the first portion of the working fluid through the RHX system, the CHX system, the generation compressor system, and the RHX system.
 209. The method of any one of claim 205, 206, 207, or 208, wherein the method further comprises transitioning the PHES system from the generation mode operation to the hot turning mode operation.
 210. The method of any one of claim 205, 206, 207, or 208, wherein the method further comprises transitioning the PHES system from the hot turning mode operation to the generation mode operation.
 211. The method of any one of claim 205, 206, 207, or 208, wherein turning the generation compressor at the generation compressor slow-rolling speed comprises turning the generation compressor via a turning motor (221-1).
 212. The method of any one of claim 205, 206, 207, or 208, wherein the generation mode operation further comprises: turning the generation compressor at a second generation-mode operating speed; and wherein the hot turning mode operation further comprises: turning the generation compressor at a generation compressor slow-rolling speed, wherein the generation compressor slow-rolling speed is less than the second generation-mode operating speed, and recirculating a second portion of the working fluid through the generation compressor without circulating the second portion of the working fluid through the RHX system, the HHX system, the generation turbine system, and the CHX system.
 213. The method of any one of claim 205, 206, 207, or 208, wherein the generation mode operation further comprises flowing the CTS medium through the CHX and flowing the HTS medium through the HHX, and wherein the hot turning mode operation further comprises not flowing the CTS medium through the CHX and not flowing the HTS medium through the HHX.
 214. The method of any one of claim 205, 206, or 208, wherein the hot turning mode operation further comprises not circulating the working fluid through the first working fluid path.
 215. The method of any one of claim 205, 207, or 208, wherein the hot turning mode operation further comprises not transferring thermal energy between the HTS medium and the CTS medium.
 216. The method of any one of claim 205, 206, 207, or 208, wherein the hot turning mode operation further comprises: turning a charge compressor (130-1) at a charge compressor slow-rolling speed; and recirculating a second portion of the working fluid through the charge compressor without circulating the second portion of the working fluid through the HHX system, the RHX system, a charge turbine (140-1), and the CHX system.
 217. A method of operating a pumped heat energy storage system (“PHES system”), the method comprising: operating the PHES system in a generation mode (1004), the generation mode operation comprising: circulating a working fluid through, in sequence, a first working fluid path comprising: a generation compressor (230-1), a recuperator heat exchanger (“RHX”) (400-1), a hot-side heat exchanger (“HHX”) (500-1), a generation turbine (240-1), the RHX, a cold-side heat exchanger (“CHX”) (600-1), and back to the generation compressor, wherein the circulating working fluid is in thermal contact with a cold-side thermal storage (“CTS”) medium (690) and a hot-side thermal storage (“HTS”) medium (590), wherein the circulating working fluid transfers thermal energy from the HTS medium to the CTS medium, and turning a generator (210-1) at a generation-mode operating speed via the generation turbine; and operating the PHES system in a hot turning mode (1006), the hot turning mode operation comprising: turning a charge compressor (130-1) at a charge compressor slow-rolling speed.
 218. The method of claim 217, wherein the hot turning mode operation further comprises: wherein the working fluid is not transferring thermal energy between the CTS medium and the HTS medium.
 219. The method of claim 217, wherein the hot turning mode operation further comprises: preventing circulation of the working fluid through the first working fluid path.
 220. The method of claim 217, wherein the hot turning mode operation further comprises: preventing circulation of the working fluid through a second working fluid path comprising, in sequence: the charge compressor, the HHX, the RHX, a charge turbine (140-1), the CHX, the RHX, and back to the charge compressor.
 221. The method of claim 217, wherein the hot turning mode operation further comprises: recirculating a portion of the working fluid through the charge compressor without circulating the second portion of the working fluid through the HHX system, the RHX system, a charge turbine (140-1), and the CHX system.
 222. A method of operating a pumped heat energy storage system (“PHES system”), the method comprising: operating the PHES system in a charge mode (1002), the charge mode operation comprising: turning a charge compressor (130-1) at a charge-mode operating speed via a primary motor (110-1), and circulating a working fluid through, in sequence, a first working fluid path comprising: the charge compressor, a hot-side heat exchanger (“HHX”) (500-1), a recuperator heat exchanger (“RHX”) (400-1), a charge turbine (140-1), a cold-side heat exchanger (“CHX”) (600-1), the RHX, and back to the charge compressor, flowing a cold-side thermal storage (“CTS”) medium (690) through the CHX, wherein the flowing CTS medium is in thermal contact with the circulating working fluid, flowing a hot-side thermal storage (“HTS”) medium (590) through the HHX, wherein the flowing HTS medium is in thermal contact with the circulating working fluid, and wherein the circulating working fluid in the first working fluid path transfers thermal energy from the CTS medium to the HTS medium; operating the PHES system in a generation mode (1004), the generation mode operation comprising: circulating a working fluid through, in sequence, a second working fluid path comprising: a generation compressor (230-1), the RHX, the HHX, a generation turbine (240-1), the RHX, the CHX, and back to the generation compressor, flowing the CTS medium through the CHX, wherein the flowing CTS medium is in thermal contact with the circulating working fluid, flowing the HTS medium through the HHX, wherein the flowing HTS medium is in thermal contact with the circulating working fluid, wherein the circulating working fluid in the second working fluid path transfers thermal energy from the HTS medium to the CTS medium, and turning a generator (210-1) at a generation-mode operating speed via the generation turbine; and operating the PHES system in a hot standby mode (1006), the hot standby mode operation comprising: maintaining a turning speed of the charge compressor at substantially zero revolutions per minute, maintaining a turning speed of the generation turbine at substantially zero revolutions per minute, and maintaining the HHX above an ambient temperature.
 223. The method of claim 222, wherein the method further comprises transitioning the PHES system from the hot standby mode operation to the charge mode operation.
 224. The method of claim 222, wherein the method further comprises transitioning the PHES system from the hot standby mode operation to the generation mode operation.
 225. The method of claim 222, wherein maintaining the HHX above an ambient temperature further comprises heating the HHX with a heat trace.
 226. The method of claim 222, wherein maintaining the HHX above an ambient temperature comprises flowing the HTS medium through the HHX.
 227. The method of claim 226, wherein a flowrate of the HTS medium through the HHX during the hot standby mode operation is lower than a flowrate of the HTS medium through the HHX during the charge mode operation, and wherein the flowrate of the HTS medium through the HHX during the hot standby mode operation is lower than a flowrate of the HTS medium through the HHX the generation mode operation.
 228. The method of claim 226, wherein maintaining the HHX above an ambient temperature further comprises heating the HTS medium with a heat trace (560).
 229. The method of claim 226, wherein maintaining the HHX above an ambient temperature further comprises heating the HTS medium with a heater (512, 522).
 230. The method of claim 222, wherein maintaining the HHX above an ambient temperature comprises maintaining the HHX substantially at a temperature that the HHX operates at during charge mode operation or generation mode operation.
 231. The method of claim 222, further comprising maintaining a pressure of the working fluid in the CHX greater that a pressure of the CTS medium in the CHX.
 232. The method of claim 222, further comprising maintaining a pressure of the working fluid in the HHX greater that a pressure of the HTS medium in the HHX.
 233. A method of transitioning a pumped heat energy storage system (“PHES system”) from a hot standby state to a generation state, wherein the PHES system includes a generation-mode working fluid path comprising, in sequence, a generation compressor system (230), a recuperator heat exchanger (“RHX”) system (400), a hot-side heat exchanger (“HHX”) system (500), a generation turbine system (240), the RHX system, a cold-side heat exchanger (“CHX”) system (600), and back to the generation compressor system, and wherein the PHES system includes a charge-mode working fluid path comprising, in sequence, a charge compressor system (130), the HHX system, the RHX system, a charge turbine system (140), the CHS system, the RHX, and back to the charge compressor system, the method comprising, in sequence: first, operating the PHES system in a hot standby state, the hot standby state comprising: a generation powertrain is not turning, wherein the generation powertrain comprises the generation compressor system and the generation turbine system, a charge powertrain is not turning, wherein the charge powertrain comprises the charge compressor system and the charge turbine system, and a working fluid is not circulating in the generation-mode working fluid path; second, transitioning the PHES, the transitioning step comprising: opening a generation bypass valve (229), wherein the open generation bypass valve permits at least a portion of the working fluid to circulate in a bypass fluid path comprising, in sequence, the generation compressor system, the generation bypass valve, a low-pressure side of the RHX system, the CHX system, and back to the generation compressor system, spinning up the generation powertrain towards a generation-mode operating speed, circulating the working fluid in the generation-mode working fluid path, and circulating at least the portion of the working fluid in the bypass fluid path, bypassing a high-pressure side of RHX system and the HHX system; and third, operating the PHES system in a generation state, the generation state comprising: the generation powertrain is operating at a generation-mode operating speed, the working fluid is circulating in the generation-mode working fluid path, and the generation bypass valve is in a closed state.
 234. The method of claim 233, wherein the hot standby state further comprises: one or more generation isolation valves are in a closed state, wherein the one or more closed generation isolation valves prevent circulation of the working fluid through the generation-mode working fluid path; wherein the transitioning step further comprises: opening the one or more generation isolation valves, wherein the working fluid then circulates through the generation-mode working fluid path; and wherein the generation state further comprises: the one or more generation isolation valves are in an open state.
 235. The method of claim 234, wherein the one or more generation isolation valves comprises a generation compressor isolation valve (231), wherein the generation compressor isolation valve in a closed state prevents circulation of a working fluid from the generation compressor system through the generation-mode working fluid path.
 236. The method of claim 234, wherein the one or more generation isolation valves comprises a generation turbine isolation valve (241), wherein the generation turbine isolation valve in a closed state prevents circulation of the working fluid from the generation-mode working fluid path through the generation turbine system.
 237. The method of any one of claim 233 or 234, wherein spinning up the generation powertrain towards a generation-mode operating speed comprises driving the generation powertrain via a variable frequency drive.
 238. The method of claim 237, wherein the generation state further comprises: the generation powertrain is not connected to the variable frequency drive; and the generation powertrain is connected to an electrical grid.
 239. The method of any one of claim 233 or 234, wherein the hot standby state further comprises, a hot-side thermal storage (“HTS”) medium (590) is residing in the HHX system and not flowing through the HHX system, and wherein the transitioning step further comprises: flowing the HTS medium through the HHX system while spinning up the generation powertrain towards a generation-mode operating speed.
 240. The method of any one of claim 233 or 234, wherein the hot standby state further comprises a hot-side thermal storage (“HTS”) medium (590) is in the HHX system, and wherein the transitioning step further comprises: flowing the HTS medium through the HHX system at a flow rate greater than in the hot standby state while spinning up the generation powertrain towards a generation-mode operating speed.
 241. The method of any one of claim 233 or 234, wherein the hot standby state further comprises a cold-side thermal storage (“CTS”) medium (690) is residing in the CHX system and not flowing through the CHX system, and wherein the transitioning step further comprises: flowing the CTS medium through the CHX system while spinning up the generation powertrain towards a generation-mode operating speed.
 242. The method of any one of claim 233 or 234, wherein the hot standby state further comprises a cold-side thermal storage (“CTS”) medium (690) is in the CHX system, and wherein the transitioning step further comprises: flowing the CTS medium through the CHX system at a flow rate greater than in the hot standby state while spinning up the generation powertrain towards a generation-mode operating speed.
 243. The method of any one of claim 233 or 234, wherein the hot standby state further comprises an ambient heat exchanger (“AHX”) system (700) arranged in the generation-mode working fluid path.
 244. The method of any one of claim 233 or 234, wherein circulating the working fluid in the generation-mode working fluid path comprises circulating the working fluid through an ambient heat exchanger (“AHX”) system (700) arranged in the generation-mode working fluid path.
 245. The method of any one of claim 233 or 234, wherein the generation state further comprises an ambient heat exchanger (“AHX”) system (700) arranged in the generation-mode working fluid path.
 246. A method of transitioning a pumped heat energy storage system (“PHES system”) from a hot standby state to a charge state, wherein the PHES system includes a generation-mode working fluid path comprising, in sequence, a generation compressor system (230), a recuperator heat exchanger (“RHX”) system (400), a hot-side heat exchanger (“HHX”) system (500), a generation turbine system (240), the RHX system, a cold-side heat exchanger (“CHX”) system (600), and back to the generation compressor system, and wherein the PHES system includes a charge-mode working fluid path comprising, in sequence, a charge compressor system (130), the HHX system, the RHX system, a charge turbine system (140), the CHS system, the RHX, and back to the charge compressor system, the method comprising, in sequence: first, operating the PHES system in a hot standby state, the hot standby state comprising: a charge powertrain is not turning, wherein the charge powertrain comprises the charge compressor system and the charge turbine system, a generation powertrain is not turning, wherein the generation powertrain comprises the generation compressor system and the generation turbine system, and a working fluid is not circulating in the charge-mode working fluid path; second, transitioning the PHES, the transitioning step comprising: spinning up the charge powertrain towards a charge-mode operating speed, circulating the working fluid in the charge-mode working fluid path, and recirculating at least a portion of the working fluid in a recirculation fluid path through the charge compressor system via an open recirculation valve (119), bypassing the HHX system, the RHX system, the charge turbine system, and the CHX system; and third, operating the PHES system in a charge state, the charge state comprising: the charge powertrain is operating at a charge-mode operating speed, the working fluid is circulating in the charge-mode working fluid path, and the recirculation valve is in a closed state.
 247. The method of claim 246, wherein the hot standby state further comprises: one or more charge isolation valves are in a closed state, wherein the one or more closed charge isolation valves prevent circulation of the working fluid through the charge-mode working fluid path; wherein the transitioning step further comprises: opening the one or more charge isolation valves, wherein the working fluid then circulates through the charge-mode working fluid path; and wherein the generation state further comprises: the one or more charge isolation valves are in an open state.
 248. The method of claim 247, wherein the one or more charge isolation valves comprises a charge compressor isolation valve (131), wherein the charge compressor isolation valve in a closed state prevents circulation of a working fluid from the charge compressor system through the charge-mode working fluid path.
 249. The method of claim 247, wherein the one or more charge isolation valves comprises a charge turbine isolation valve (141), wherein the charge turbine isolation valve in a closed state prevents circulation of the working fluid from the charge-mode working fluid path through the charge turbine system.
 250. The method of any one of claim 246 or 247, wherein spinning up the charge powertrain towards a charge-mode operating speed comprises driving the charge powertrain via a variable frequency drive.
 251. The method of claim 250, wherein the charge state further comprises: the charge powertrain is not connected to the variable frequency drive; and the charge powertrain is connected to an electrical grid.
 252. The method of any one of claim 246 or 247, wherein the hot standby state further comprises, a hot-side thermal storage (“HTS”) medium (590) is residing in the HHX system and not flowing through the HHX system, and wherein the transitioning step further comprises: flowing the HTS medium through the HHX system while spinning up the charge powertrain towards a charge-mode operating speed.
 253. The method of any one of claim 246 or 247, wherein the hot standby state further comprises a hot-side thermal storage (“HTS”) medium (590) is in the HHX system, and wherein the transitioning step further comprises: flowing the HTS medium through the HHX system at a flow rate greater than in the hot standby state while spinning up the charge powertrain towards a charge-mode operating speed.
 254. The method of any one of claim 246 or 247, wherein the hot standby state further comprises a cold-side thermal storage (“CTS”) medium (690) is residing in the CHX system and not flowing through the CHX system, and wherein the transitioning step further comprises: flowing the CTS medium through the CHX system while spinning up the charge powertrain towards a charge-mode operating speed.
 255. The method of any one of claim 246 or 247, wherein the hot standby state further comprises a cold-side thermal storage (“CTS”) medium (690) is in the CHX system, and wherein the transitioning step further comprises: flowing the CTS medium through the CHX system at a flow rate greater than in the hot standby state while spinning up the charge powertrain towards a charge-mode operating speed.
 256. A method of transitioning a pumped heat energy storage system (“PHES system”) from a charge state to a hot turning state, wherein the PHES system includes a generation-mode working fluid path comprising, in sequence, a generation compressor system (230), a recuperator heat exchanger (“RHX”) system (400), a hot-side heat exchanger (“HHX”) system (500), a generation turbine system (240), the RHX system, a cold-side heat exchanger (“CHX”) system (600), and back to the generation compressor system, and wherein the PHES system includes a charge-mode working fluid path comprising, in sequence, a charge compressor system (130), the HHX system, the RHX system, a charge turbine system (140), the CHS system, the RHX, and back to the charge compressor system, the method comprising, in sequence: first, operating the PHES system in a charge state, the charge state comprising: the working fluid is circulating through the charge-mode working fluid path, and a charge powertrain is operating at a charge-mode operating speed, wherein the charge powertrain comprises the charge compressor system and the charge turbine system; second, transitioning the PHES, the transitioning step comprising: opening a first recirculation fluid path, wherein at least a portion of the working fluid then recirculates through the open first recirculation fluid path through the charge compressor system, bypassing the HHX system, the RHX system, the charge turbine system, and the CHX system, and preventing circulation of the working fluid through the charge-mode working fluid path; and third, operating the PHES system in a hot turning state, the hot turning state comprising: the charge powertrain is operating at a charge-mode slow-rolling speed, and a second recirculation fluid path is open, wherein at least a portion of the working fluid is recirculating through the open second recirculation fluid path through the charge compressor system, bypassing the HHX system, the RHX system, the charge turbine system, and the CHX system.
 257. The method of claim 256, wherein the first recirculation fluid path comprises a recirculation valve (119) operable to open and close the first recirculation fluid path.
 258. The method of claim 256, wherein the second recirculation fluid path comprises a recirculation valve (132) operable to open and close the second recirculation fluid path.
 259. The method of claim 256, wherein the first recirculation fluid and the second recirculation fluid path are the same recirculation fluid path.
 260. The method of claim 256, wherein the hot turning state further comprises: a third recirculation fluid path is open, wherein at least a portion of the working fluid is recirculating through the open third recirculation fluid path through the charge turbine system, bypassing the CHX system, the RHX system, the charge compressor system, and the HHX system.
 261. The method of claim 260, wherein the third recirculation fluid path comprises a recirculation valve (142) operable to open and close the third recirculation fluid path.
 262. The method of claim 256, wherein the hot turning state further comprises: the working fluid is not circulating through the charge-mode working fluid path; and the working fluid is not circulating through the generation-mode working fluid path.
 263. The method of claim 256, wherein preventing circulation of the working fluid through the charge-mode working fluid path comprises closing a charge compressor isolation valve (131), wherein the closed charge compressor isolation valve prevents circulation of the working fluid from the charge compressor system through the charge-mode working fluid path.
 264. The method of claim 256, wherein preventing circulation of the working fluid through the charge-mode working fluid path comprises closing a charge turbine isolation valve (141), wherein the closed charge turbine isolation valve prevents circulation of the working fluid from the charge-mode working fluid path through the charge turbine system.
 265. The method of claim 256, wherein the hot turning state further comprises: a generation powertrain is not turning, wherein the generation powertrain comprises the generation compressor system and the generation turbine system.
 266. A method of transitioning a pumped heat energy storage system (“PHES system”) from a generation state to a hot turning state, wherein the PHES system includes a generation-mode working fluid path comprising, in sequence, a generation compressor system (230), a recuperator heat exchanger (“RHX”) system (400), a hot-side heat exchanger (“HHX”) system (500), a generation turbine system (240), the RHX system, a cold-side heat exchanger (“CHX”) system (600), and back to the generation compressor system, and wherein the PHES system includes a charge-mode working fluid path comprising, in sequence, a charge compressor system (130), the HHX system, the RHX system, a charge turbine system (140), the CHS system, the RHX, and back to the charge compressor system, the method comprising, in sequence: first, operating the PHES system in a generation state, the generation state comprising: the working fluid is circulating through the generation-mode working fluid path, and a generation powertrain is operating at a generation-mode operating speed, wherein the generation powertrain comprises the generation compressor system and the generation turbine system; second, transitioning the PHES, the transitioning step comprising: opening a bypass fluid path, wherein at least a portion of the working fluid then circulates through the open bypass fluid path from an outlet of the generation compressor system to an inlet of a low-pressure side of the RHX system, bypassing a high-pressure side of the RHX system, the HHX system, and the generation turbine system, and preventing circulation of the working fluid through the generation-mode working fluid path; and third, operating the PHES system in a hot turning state, the hot turning state comprising: the generation powertrain is operating at a generation-mode slow-rolling speed, the bypass fluid path is closed, preventing circulation of at least the portion of the working fluid through the bypass fluid path, and a first recirculation fluid path is open, wherein the open first recirculation fluid path permits recirculation of at least a portion of the working fluid through the generation turbine system, bypassing the RHX system, the CHX system, the generation compressor system, and the HHX system.
 267. The method of claim 266, wherein the first recirculation fluid path comprises a recirculation valve (242) operable to open and close the first recirculation fluid path.
 268. The method of claim 266, wherein the hot turning state further comprises: a second recirculation fluid path is open, wherein the open second recirculation fluid path permits recirculation of at least a portion of the working fluid through the generation compressor system, bypassing the RHX system, the HHX system, the generation turbine system, and the CHX system.
 269. The method of claim 268, wherein the second recirculation fluid path comprises a recirculation valve (232) operable to open and close the second recirculation fluid path.
 270. The method of claim 266, wherein the hot turning state further comprises: the working fluid is not circulating through the charge-mode working fluid path; and the working fluid is not circulating through the generation-mode working fluid path.
 271. The method of claim 266, wherein preventing circulation of the working fluid through the generation-mode working fluid path comprises closing a generation compressor isolation valve (231), wherein the closed generation compressor isolation valve prevents circulation of the working fluid from the generation compressor system through the generation-mode working fluid path.
 272. The method of claim 266, wherein preventing circulation of the working fluid through the charge-mode working fluid path comprises closing a generation turbine isolation valve (241), wherein the closed generation turbine isolation valve prevents circulation of the working fluid from the generation-mode working fluid path through the generation turbine system.
 273. The method of claim 266, wherein the hot turning state further comprises: a charge powertrain is not turning, wherein the charge powertrain comprises the charge compressor system and the charge turbine system. 